2021 Annual Report
Visionin Motion
Contents
2 Chairman’s Message
10
A more just and equitable society
5
Financial Highlights
12
Bigger than our bottom line
6
Cleaner energy from a transformed fleet
14
Leadership
8
A reliable and resilient system
16
Financial Contents
Every day at Southern Company, we put into motion
our vision for the future of energy. It encompasses
our century-long commitment to provide clean,
safe, reliable and affordable energy to the customers
we are privileged to serve, while making life in our
communities better because we are there. Knowing
that tomorrow’s needs are on today’s doorstep,
we are aggressively working toward our net-zero
emissions goal by transforming our generation fleet,
researching next-generation energy technologies and
constructing the first new nuclear units to be built in
the U.S. in a generation. As we make smarter moves
for our climate, we are delivering a more reliable and
resilient system and advancing diversity, equity and
inclusion in our workplace and in our communities.
That’s our vision. Explore this report to learn more
about how we put it in motion.
1
Chairman’s Message
Dear fellow shareholders,
At Southern Company, our vision is rooted in knowing
Notable highlights from 2021 are perhaps best appreciated
energy provides an opportunity for people to live more
through a brief review of the progress we achieved in each
comfortable and connected lives, fuels businesses that
of our five strategic priorities:
are shaping industries and creates possibilities for future
generations. We put our vision in motion by placing our
customers and communities at the center of everything
we do. Understanding their needs and going out of our
way to prepare them for what’s ahead, our mission
remains the same – provide clean, safe, reliable and
affordable energy. Over 27,000 system employees work
hard every day to deliver smart solutions anchored in
remarkable service, resilience and safety.
Excel at the Fundamentals
Southern Company’s keen focus on operational excellence
and business fundamentals has resulted in a variety of
industry awards and recognition. Nicor Gas was honored
with the Midwest Energy Efficiency Alliance Award for
outstanding service to customers in need. The Edison
Electric Institute recognized Alabama Power with the
Emergency Response Award. Virginia Natural Gas was
recognized by the Virginia Oil and Gas Association as
In fact, here in the first few months of 2022, we were
that state’s Local Distribution Company of the Year.
recognized by Fortune magazine as one of the World’s
Most Admired Companies. This recognition is a testament
to the thousands of people across our enterprise who are
making thousands of good decisions every day in align-
ment with our core values of Safety First, Unquestionable
Trust, Superior Performance and Total Commitment.
You will find photographs of some of these employees
J.D. Power ranked Georgia Power among the very best
in business customer satisfaction for large utilities in the
South. Cogent Reports named both Georgia Power and
Nicor Gas among their most trusted utility brands, and
Chattanooga Gas among the most trusted business
partners in the utility industry.
displayed throughout this report. These individuals–and
Achieve Success with Major Construction Projects
countless others–are the basis for our continued success,
Despite the COVID-19 pandemic, we continued to make
and I am proud to serve on their team.
This past year was an outstanding year for Southern
Company, and we believe we are well-positioned to
continue that momentum. We have a solid financial
outlook, and our premier, state-regulated electric
and gas utility franchises continue to be among our
industry’s leaders for operational performance and
customer satisfaction.
In 2021, Southern Company benefitted from strong
customer growth, improving retail trends and continued
investment in our state rate-regulated utilities. On an
adjusted basis*, our company earned $3.62 billion, or $3.41
per share, compared with $3.44 billion, or $3.25 per share,
meaningful progress at Plant Vogtle units 3 and 4, and
we are entering the final stages of testing for Unit 3.
The project has continued to face challenges which have
added to our project timelines and costs. The projected
in-service range for Unit 3 is the fourth quarter of 2022
through the first quarter of 2023. We project that Unit 4
will be in service in the third or fourth quarter of 2023.
All 157 fuel assemblies at Unit 3 have been loaded into
the spent fuel pool in preparation for fuel load. Direct
construction of Unit 4 is approximately 92% complete.
Our priority is bringing these units online safely, after
which they are expected to serve as reliable carbon-free
energy resources for customers for the next 60 to 80 years.
for 2020. For nearly three quarters of a century, Southern
Support the Building of a National Energy Policy
Company has paid a dividend to its shareholders that is
We maintained our ongoing commitment to advocate for
equal to or greater than the previous quarter.
a comprehensive national energy policy, actively engaging in
* Adjusted earnings per share is not a financial measure under generally accepted accounting principles. See Reconciliation of
Non-GAAP Financial Metric on page 21 for additional information and specific adjustments made to this measure by year.
2
Thomas A. Fanning
Chairman, President & CEO,
Southern Company
3
Chairman’s Message (continued)
public policy dialogue and working constructively with regulators
For the sixth consecutive year, we were recognized as one of
and legislators to support policies that advance innovation and
the Top 50 Companies for Diversity by DiversityInc. Southern
benefit our industry, our business and the customers we serve.
Company earned a 100 percent rating from the Human Rights
Promote Energy Innovation
Southern Company and the United States Department of
Energy have established a cooperative agreement to design,
construct and operate the Molten Chloride Reactor Experiment–
Campaign (HRC) on their 2022 Corporate Equality Index, also
for the sixth consecutive year. Likewise, the HRC’s Disability
Equality Index recognized Southern Company as one of the
Best Places to Work for Disability Inclusion.
the world’s first critical fast-spectrum salt reactor and a tech-
We also take great pride in our longstanding commitment to
nology considered important to a sustainable clean energy
hiring military veterans. In 2021, we were named the number
future. Southern Company’s research and development (R&D)
one Best for Vets Employer by Military Times magazine.
organization will lead this effort in collaboration with Terra-
Power, Idaho National Laboratory, CORE POWER, Orano Federal
Services, the Electric Power Research Institute and 3M Company.
I believe all these accolades are a tangible result of our
commitment to value and develop our people, and our efforts
to create a workplace where all groups are well-represented,
Southern Company has also joined the Hydrogen Council, a
included and treated fairly and where everyone feels welcome,
global, CEO-led coalition of companies with a united vision
valued and respected.
and long-term ambition for hydrogen to foster a clean energy
transition. The Council believes hydrogen will play a key role
in reaching global decarbonization goals by helping diversify
energy sources and by fostering business and technological
innovation. Southern Company is embracing the role of hydrogen
as a potentially powerful solution to holistically serve the
needs of customers while providing a resilient energy system
in a decarbonized energy environment.
Southern Company’s R&D organization is actively engaged
both domestically and internationally in a portfolio of projects
focused on power generation delivery, transportation,
infrastructure and energy storage, as well as low-carbon
hydrogen production and developing a national road map
for the deployment of hydrogen-based energy.
Value and Develop Our People
Southern Company has been named the number two Best
In closing, the foundation of our business remains strong as
we continue to execute on our vision. With performance
characterized by outstanding fundamentals, high customer
satisfaction, operational excellence and constructive regulatory
relationships, our success is the direct result of an unwavering
emphasis on the core values that have shaped our company’s
identity since its inception.
Our customer-focused business model continues to be the
cornerstone for delivering value to customers and shareholders
alike, and our management team is experienced and motivated,
with a long track record of successfully executing on this
time-tested model. We believe our company is poised for
continued success, both today and in the years ahead.
We are grateful for your continued confidence in Southern
Company. It is a privilege to serve you.
Large Employer in America by Forbes magazine. Of the 500
Sincerely,
large employers included in the ranking, Southern Company
was first among energy industry peers, first among Georgia-
based companies and first in the entire Southeast. This
recognition is especially gratifying because it was based
Thomas A. Fanning
directly on employee feedback.
March 29, 2022
4
Financial Highlights
4.53
2.95
2.18
2.26
0.84
3.02
3.07
3.11
3.25
3.41
’17
’18
’19
’20
’21
’17
’18
’19
’20
’21
Basic Earnings Per Share
(in dollars)
Basic Earnings Per Share–Excluding Items*
(in dollars)
* Not a financial measure under generally accepted accounting principles.
See Reconciliation of Non-GAAP Financial Metric on page 21 for additional
information and specific adjustments made to this measure by year.
2.30
2.38
2.46
2.54
2.62
18.15
9.11
11.24
8.57
3.44
’17
’18
’19
’20
’21
’17
’18
’19
’20
’21
Return On Average Common Equity
(percent)
Dividends Per Share
(in dollars)
2021
2020
Change
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)
$23,113
$2,393
$2.26
$2.24
$2.62
3.8
1,061
8.57
$26.30
$68.58
Total Market Value Of Common Stock (year-end, in millions)
$72,693
Total Assets (in millions)
Total Kilowatt-Hour Sales (in millions)
Retail
Wholesale
Total Utility Customers (year-end, in thousands)
$127,534
193,380
143,370
50,010
8,722
$20,375
$3,119
$2.95
$2.93
$2.54
4.1
1,058
11.24
$26.48
$61.43
$64,899
$122,935
186,225
140,546
45,679
8,630
13.4)%
(23.3)%
(23.4)%
(23.5)%
3.1)%
(7.3)%
0.3)%
(23.8)%
(0.7)%
11.6)%
12.0)%
3.7)%
3.8)%
2.0)%
9.5)%
1.1)%
5
Energy Mix*
Southern Company System
D.
A.
B.
C.
2007
A. 16% Gas
B. 14% Nuclear
C. 69% Coal
D. 1% Renewables/Other
D.
C.
A.
B.
2021
A. 48% Gas
B. 16% Nuclear
C. 21% Coal
D. 15% Renewables/Other
6
* Represents the energy the Southern Company system uses to serve its retail and wholesale customers. Does not represent any particular customer or
customer class. Includes non-affiliate PPAs. Renewables/Other includes wind, solar, hydro, biomass and landfill gas. For certain renewable generation and
associated renewable energy credits (RECs), to the extent an affiliate of Southern Company has the right to the RECs associated with renewable energy
it generates or purchases, it retains the right to sell the energy and RECs, either bundled or separately, to retail customers and third parties.
The vision:
Cleaner energy from
a transformed fleet
We are aggressively transforming our energy generation fleet to lower
carbon-emitting sources to better serve customers and communities
with cleaner energy.
We like to say that innovation is in our DNA, and across the Southern Company system
we work hard each day to deliver increasingly clean energy with the same safety,
reliability and affordability that our customers have come to expect.
In 2021, nearly one third of our energy mix came from zero-carbon sources, including
renewables like solar, wind and hydro, and carbon-free nuclear energy. Over the past
15 years, we have closed or repowered 46 coal-fired generating units, representing
over 9,000 megawatts. We are working in lockstep with our state regulators through
integrated resource planning processes to transform our energy generation fleet, adding
more renewables and modernizing our hydroelectric generation.
Southern Company is targeting net zero greenhouse gas (GHG) emissions by 2050.
Net zero is a scenario where any GHG emissions from operations are balanced by an
equivalent amount of GHG removal. Southern Company Gas is continuing to modernize
its infrastructure to help ensure that the natural gas we deliver to homes and businesses
is clean, safe, reliable and affordable.
At the same time, our industry-leading R&D organization is on the front lines developing
energy storage solutions and zero-carbon technologies. As we plan for this energy future,
we are carefully coordinating the development of these new resources with the grid to
help ensure continued reliability and resilience.
We are off to a great start on our goal, and expect to sustainably achieve an interim
50% reduction in GHG emissions by 2025, compared with 2007 baseline levels–five
years in advance of our target of 2030.
(Left) Skookumchuck Wind Facility, located in Lewis and Thurston Counties, Washington.
Skookumchuck is one of the newest renewable generating facilities of Southern Power,
Southern Company’s wholesale energy subsidiary.
7
The vision:
A reliable and resilient
system second to none
Delivering the future of energy requires that we protect that future.
Southern Company employs multiple layers of security to help ensure
the resilience of our system.
Since the inception of Southern Company more than 100 years ago, the delivery of
energy to homes and businesses has changed significantly. No longer just a matter of
power poles or pipelines, advanced technology is now an integral part of the process.
Protecting those technological assets from cyber threats is just as important as protecting
our physical assets.
“Cybersecurity has become paramount, day in and day out,” explains Martin Davis, chief
information officer (CIO) for Southern Company. “As a critical part of the infrastructure
of the United States, we’ve got to protect it at all costs.” Just as cyber threats are ever-
changing, Southern Company is ever-diligent in its efforts to protect its technological assets.
“We employ a ‘defense in-depth’ approach to cybersecurity,” adds Davis. “This is very
similar to the way in which you might seek to protect your home. For example, you
might have a doorbell camera at your front door, an alarm system and perhaps other
surveillance cameras inside your home. Our approach to cybersecurity is much the
same, with layers of defense for our network, our telecommunications, our computers
and our data.”
As CIO, Davis oversees more than 2,000 employees in the company’s Technology
Organization, including a dedicated team who staff our Security Operations Center,
where company operations are monitored around the clock.
(Right) Employees at Southern Company’s Security Operations Center are on the front lines of the
company’s 24/7 cybersecurity efforts.
8
9
The vision:
A more just and
equitable society
Southern Company has long been a leader in the fight for social justice
and equity, both in the workplace and in the communities we serve.
This commitment guides not only our business priorities and partnerships, it informs
our approach to philanthropic giving as we endeavor to bolster equity for all groups,
especially underserved or historically marginalized groups.
In 2021, we continued to assess how we conduct our business and what improvements
might serve to advance these objectives. We implemented measures designed to
eliminate unconscious bias from our hiring process. Underscoring our commitment to
supplier diversity, Southern Company subsidiaries established a goal to increase their
utilization of minority-owned businesses to 30% of total spend. We invested more
than $66 million to advance racial equity and social justice in our communities as part
of a larger commitment to invest $225 million through 2025. This social justice strategy
targets giving of $25 million to advance energy justice, $50 million to promote criminal
justice reform, $50 million for economic empowerment and $100 million to advance
educational equity.
Among the highlights of our philanthropic giving in 2021 was a landmark $5 million
donation by the Southern Company Foundation to establish the Center for Civil Rights
and Social Justice at the Emory University School of Law. The Foundation has also
announced $10 million in grants to fund a new and innovative collaboration between
INROADS, one of the nation’s largest nonprofit developers of underrepresented talent,
the United Negro College Fund and the Thurgood Marshall College Fund, all global leaders
in providing financial support to students at Historically Black Colleges and Universities.
Finally, we published our first-ever Southern Company Transformation Report to
document our progress against these goals of increased cultural understanding and
community involvement.
(Right) Employees representing a variety of Southern Company subsidiaries meeting at the
Energy Center in Birmingham, Alabama.
10
11
Employees throughout the Southern Company system regularly volunteer for a myriad of conservation-minded projects such as tree plantings.
12
The vision:
Bigger than our
bottom line
We are committed to being “A Citizen Wherever We Serve,” meaning our
employees are inextricably woven into the communities we are privileged
to serve.
At Southern Company, we have long believed corporate responsibility and corporate strategy
At Southern Company, we have long believed corporate responsibility and corporate strategy
should be closely linked. Employee volunteerism and support of community initiatives,
should be closely linked. Employee volunteerism and support of community initiatives,
both large and small, are hallmarks of Southern Company and our subsidiaries. Employees
both large and small, are hallmarks of Southern Company and our subsidiaries. Employees
and retirees dedicate approximately 200,000 hours of volunteer service annually to support
and retirees dedicate approximately 200,000 hours of volunteer service annually to support
and improve our communities. In 2021, charitable giving across the Southern Company System
and improve our communities. In 2021, charitable giving across the Southern Company System
totaled $110 million. We are committed to investing more than $225 million in community
totaled $110 million. We are committed to investing more than $225 million in community
social justice efforts through 2025.
social justice efforts through 2025.
Similarly, our environmental goals and progress remain core to Southern Company’s overall
Similarly, our environmental goals and progress remain core to Southern Company’s overall
strategy and corporate responsibility. The pillars of our environmental strategy are leading
strategy and corporate responsibility. The pillars of our environmental strategy are leading
through innovation, promoting conservation and environmental stewardship, engaging
through innovation, promoting conservation and environmental stewardship, engaging
in robust research and development and holding ourselves accountable with transparent
in robust research and development and holding ourselves accountable with transparent
reporting. These concepts guide how we conduct business.
reporting. These concepts guide how we conduct business.
That is why we were one of the first U.S. energy companies to establish a sustainable
That is why we were one of the first U.S. energy companies to establish a sustainable
financing framework. As of the end of 2021, we were one of the top five corporate,
financing framework. As of the end of 2021, we were one of the top five corporate,
non-financial green bond issuers in the nation.
non-financial green bond issuers in the nation.
We have a long history of partnering with communities, conservation organizations and
We have a long history of partnering with communities, conservation organizations and
natural resource agencies to help threatened and vulnerable species, restore forests, clean
natural resource agencies to help threatened and vulnerable species, restore forests, clean
waterways and increase environmental awareness. Volunteers have removed millions of tons
waterways and increase environmental awareness. Volunteers have removed millions of tons
of debris from waterways through the Renew Our Rivers program, and we have funded the
of debris from waterways through the Renew Our Rivers program, and we have funded the
preservation of land for recreational use.
preservation of land for recreational use.
Through our partnership with the National Fish and Wildlife Foundation, we have supported
Through our partnership with the National Fish and Wildlife Foundation, we have supported
hundreds of projects and invested more than $21 million in grants with a total on the ground
hundreds of projects and invested more than $21 million in grants with a total on the ground
conservation impact valued at over $180 million, restoring and enhancing over 1.9 million acres.
conservation impact valued at over $180 million, restoring and enhancing over 1.9 million acres.
13
Board of Directors
Thomas A. Fanning
Janaki Akella
Juanita Powell Baranco
Henry A. Clark III
Anthony F. Earley, Jr.
David J. Grain
Colette D. Honorable
Donald M. James
John D. Johns
Dale E. Klein
Ernest J. Moniz
William G. Smith, Jr.
Kristine L. Svinicki
E. Jenner Wood III
Management Council
Thomas A. Fanning
Bryan D. Anderson
Stanley W. Connally, Jr.
Mark A. Crosswhite
Christopher Cummiskey
Martin B. Davis
Kimberly S. Greene
James Y. Kerr II
Stephen E. Kuczynski
Daniel S. Tucker
Anthony L. Wilson
Christopher C. Womack
14
Southern Company 2021 Annual Report
Board of Directors
Thomas A. Fanning
Chairman, President and CEO, Southern Company
Atlanta, GA | Age 65 | elected 2010
Janaki Akella
Digital Transformation Leader
Google LLC (technology)
Palo Alto, CA | Age 61 | elected 2019
Juanita Powell Baranco
Executive Vice President and Chief Operating Officer
Baranco Automotive Group (automobile sales)
Atlanta, GA | Age 73 | elected 2006
Henry A. Clark III
Retired Senior Advisor, Evercore Inc.
(global independent investment advisory firm)
Hobe Sound, FL | Age 72 | elected 2009
Anthony F. Earley, Jr.
Retired Chairman, President and CEO
PG&E Corporation (utility)
Bloomfield Hills, MI | Age 72 | elected 2019
David J. Grain
CEO and Managing Director
Grain Management, LLC (private equity firm)
Sarasota, FL | Age 59 | elected 2012
Colette D. Honorable
Partner, Reed Smith LLP (legal)
Washington, DC | Age 52 | elected 2020
Donald M. James
Retired Chairman and CEO, Vulcan Materials Company (construction materials)
Pensacola, FL | Age 73 | elected 1999
John D. Johns
Retired Chairman of DLI North America Inc., the oversight company for
Protective Life Insurance Corporation (insurance)
Birmingham, AL | Age 70 | elected 2015
Dale E. Klein
Associate Vice Chancellor of Research, University of Texas System
Retired Chairman, U.S. Nuclear Regulatory Commission (energy)
Austin, TX | Age 74 | elected 2010
Ernest J. Moniz
Cecil and Ida Green Professor of Physics and Engineering Systems emeritus,
Massachusetts Institute of Technology
CEO and Co-Chair, Nuclear Threat Initiative (energy)
Former U.S. Secretary of Energy
Brookline, MA | Age 77 | elected 2018
William G. Smith, Jr.
Chairman, President and CEO, Capital City Bank Group, Inc. (banking)
Tallahassee, FL | Age 68 | elected 2006
Kristine L. Svinicki
Managing Director, The Svinicki Group LLC
Former Chairman, Nuclear Regulatory Commission
Miami Beach, FL l Age 55 l elected 2021
E. Jenner Wood III
Retired Corporate Executive Vice President–Wholesale Banking,
SunTrust Banks, Inc. (banking)
Atlanta, GA | Age 70 | elected 2012
Management Council
Thomas A. Fanning
Chairman, President and CEO
Fanning, 65, joined the company in 1980
Kimberly S. Greene
Chairman, President and CEO, Southern Company Gas
Greene, 55, has held her current role since June 2018
Bryan D. Anderson
Executive Vice President and President, External Affairs
Anderson, 55, joined the company in 2010
James Y. Kerr II
Executive Vice President, Chief Legal Officer and Chief Compliance Officer
Kerr, 58, joined the company in March 2014
Stanley W. Connally, Jr.
Executive Vice President, Operations, Southern Company
Chairman, President and Chief Executive Officer, Southern Company Services, Inc.
Connally, 52, joined the company in 1989
Mark A. Crosswhite
Chairman, President and CEO, Alabama Power
Crosswhite, 59, joined the company in 2004
Christopher Cummiskey
Executive Vice President, Chief Commercial and Customer Solutions Officer
Cummiskey, 47, joined the company in 2013
Martin B. Davis
Executive Vice President and Chief Information Officer
Davis, 59, joined the company in 2015
Stephen E. Kuczynski
Chairman, President and CEO, Southern Nuclear
Kuczynski, 59, joined the company in July 2011
Daniel S. Tucker
Executive Vice President and Chief Financial Officer
Tucker, 51, joined the company in 1998
Anthony L. Wilson
Chairman, President and CEO, Mississippi Power
Wilson, 58, joined the company in 1984
Christopher C. Womack
Chairman, President and CEO, Georgia Power
Womack, 64, joined the company in 1988
Southern Company 2021 Annual Report
15
Financial Contents
Definitions
Reconciliation of Non-GAAP Financial Metric
Cautionary Statement Regarding Forward-Looking Statements
Available Information
Southern Company Business
Five-Year Cumulative Performance Graph
17
21
22
23
24
24
25 Management’s Report on Internal Control Over Financial Reporting
26
Report of Independent Registered Public Accounting Firm
30 Management’s Discussion and Analysis of Financial Condition and Results of Operations
70
71
72
Consolidated Statements of Income
Consolidated Statements of Comprehensive Income
Consolidated Statements of Cash Flows
74 Consolidated Balance Sheets
76
77
78
Consolidated Statements of Stockholders’ Equity
Index to the Notes to Financial Statements
Notes to Financial Statements
16
Southern Company 2021 Annual Report Definitions
2013 ARP
Alternate Rate Plan approved by the Georgia PSC in 2013 for Georgia
Power for the years 2014 through 2016 and subsequently extended
through 2019
CO2
Carbon dioxide
COD
Commercial operation date
2019 ARP
Alternate Rate Plan approved by the Georgia PSC in 2019 for
Georgia Power for the years 2020 through 2022
AFUDC
Allowance for funds used during construction
Alabama Power
Alabama Power Company
Amended and Restated Loan Guarantee Agreement
Loan guarantee agreement entered into by Georgia Power with the
DOE in 2014, as amended and restated in March 2019, under which
the proceeds of borrowings may be used to reimburse Georgia Power
for Eligible Project Costs incurred in connection with its construction of
Plant Vogtle Units 3 and 4
AOCI
Accumulated other comprehensive income
ARO
Asset retirement obligation
ASC
Accounting Standards Codification
ASU
Accounting Standards Update
Atlanta Gas Light
Atlanta Gas Light Company, a wholly-owned subsidiary of
Southern Company Gas
Atlantic Coast Pipeline
Atlantic Coast Pipeline, LLC, a joint venture to construct and operate a
natural gas pipeline in which Southern Company Gas held a 5% interest
through March 24, 2020
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
Contractor Settlement Agreement
The December 31, 2015 agreement between Westinghouse and the
Vogtle Owners resolving disputes between the Vogtle Owners and the
EPC Contractor under the Vogtle 3 and 4 Agreement
Cooperative Energy
Electric generation and transmission cooperative in Mississippi
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
CPCN
Certificate of public convenience and necessity
CWIP
Construction work in progress
Dalton
City of Dalton, Georgia, an incorporated municipality in the State of
Georgia, acting by and through its Board of Water, Light, and Sinking
Fund Commissioners
Dalton Pipeline
A pipeline facility in Georgia in which Southern Company Gas has a
50% undivided ownership interest
DOE
U.S. Department of Energy
DSGP
Diamond State Generation Partners
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
EMC
Electric membership corporation
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
Clean Air Act
Clean Air Act Amendments of 1990
FASB
Financial Accounting Standards Board
17
Southern Company 2021 Annual Report Definitions
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.
GAAP
U.S. generally accepted accounting principles
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 Florida Power and Light Company, with Florida
Power and Light Company 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
IRP
Integrated resource plan
IRS
Internal Revenue Service
18
ITAAC
Inspections, Tests, Analyses, and Acceptance Criteria, standards
established by the NRC
ITC
Investment tax credit
JEA
Jacksonville Electric Authority
Jefferson Island
Jefferson Island Storage and Hub, L.L.C, which owns a natural gas
storage facility in Louisiana consisting of two salt dome caverns;
a subsidiary of Southern Company Gas through December 1, 2020
KWH
Kilowatt-hour
LIBOR
London Interbank Offered Rate
LIFO
Last-in, first-out
LNG
Liquefied natural gas
LOCOM
Lower of weighted average cost or current market price
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
MGP
Manufactured gas plant
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
Southern Company 2021 Annual Report Definitions
NDR
Alabama Power’s Natural Disaster Reserve
Rate RSE
Alabama Power’s Rate Stabilization and Equalization
NextEra Energy
NextEra Energy, Inc.
Nicor Gas
Northern Illinois Gas Company, a wholly-owned subsidiary of
Southern Company Gas
NOX
Nitrogen oxide
NRC
U.S. Nuclear Regulatory Commission
NYMEX
New York Mercantile Exchange, Inc.
NYSE
New York Stock Exchange
OCI
Other comprehensive income
OPC
Oglethorpe Power Corporation (an EMC)
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
Pivotal LNG
Pivotal LNG, Inc., through March 24, 2020, a wholly-owned subsidiary
of Southern Company Gas
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, and Rate CNP PPA
Rate ECR
Alabama Power’s Rate Energy Cost Recovery
Rate NDR
Alabama Power’s Rate Natural Disaster Reserve
Registrants
Southern Company, Alabama Power, Georgia Power, Mississippi Power,
Southern Power Company, and Southern Company Gas
ROE
Return on equity
S&P
S&P Global Ratings, a division of S&P Global Inc.
SCS
Southern Company Services, Inc., the Southern Company system service
company and a wholly-owned subsidiary of Southern Company
SEC
U.S. Securities and Exchange Commission
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
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
19
Southern Company 2021 Annual Report Definitions
Southern Power
Southern Power Company and its subsidiaries
SouthStar
SouthStar Energy Services, LLC (a Marketer), a wholly-owned subsidiary
of Southern Company Gas
SP Solar
SP Solar Holdings I, LP, a limited partnership indirectly owning
substantially all of Southern Power’s solar and battery
energy storage facilities, in which Southern Power has a 67%
ownership interest
SP Wind
SP Wind Holdings II, LLC, a holding company owning a portfolio of eight
operating wind facilities, in which Southern Power is the controlling
partner in a tax equity arrangement
SRR
Mississippi Power’s System Restoration Rider, a tariff for retail property
damage cost recovery and reserve
Subsidiary Registrants
Alabama Power, Georgia Power, Mississippi Power, Southern Power,
and Southern Company Gas
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
Triton
Triton Container Investments, LLC, an investment of Southern Company
Gas through May 29, 2019
VCM
Vogtle Construction Monitoring
VIE
Variable interest entity
Virginia Commission
Virginia State Corporation Commission
Virginia Natural Gas
Virginia Natural Gas, Inc., a wholly-owned subsidiary of
Southern Company Gas
Vogtle 3 and 4 Agreement
Agreement entered into with the EPC Contractor in 2008 by Georgia
Power, acting for itself and as agent for the Vogtle Owners, and
rejected in bankruptcy in July 2017, pursuant to which the EPC
Contractor agreed to design, engineer, procure, construct, and test Plant
Vogtle Units 3 and 4
Vogtle Owners
Georgia Power, Oglethorpe Power Corporation, MEAG Power,
and Dalton
Vogtle Services Agreement
The June 2017 services agreement between the Vogtle Owners and
the EPC Contractor, as amended and restated in July 2017, for the
EPC Contractor to transition construction management of Plant Vogtle
Units 3 and 4 to Southern Nuclear and to provide ongoing design,
engineering, and procurement services to Southern Nuclear
WACOG
Weighted average cost of gas
Westinghouse
Westinghouse Electric Company LLC
Williams Field Services Group
Williams Field Services Group, LLC
20
Southern Company 2021 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
Loss on Plant Scherer Unit 3(3)
Tax Impact
Wholesale Gas Services(4)
Tax Impact
Asset Impairments(5)
Tax Impact
Litigation Settlement Proceeds(6)
Tax Impact
Loss on Extinguishment of Debt(7)
Tax Impact
Earnings Guidance Comparability Items(8):
Equity Return Related to Kemper IGCC Schedule Extension
Tax Impact
Adoption of Tax Reform
Net Income - Excluding Items
Basic Earnings Per Share - Excluding Items
Year Ended December 31,
2021
$ 2,393
1,061
$ 2.26
2020
$3,119
1,058
$ 2.95
2019
$ 4,739
1,046
$ 4.53
2018
$ 2,226
1,020
$ 2.18
2017
$ 842
1,000
$ 0.84
$ 2,393
$3,119
$ 4,739
$ 2,226
$ 842
209
(90)
(1,703)
433
—
—
18
(3)
(91)
19
—
—
(23)
6
60
(22)
(328)
84
—
—
17
(3)
(206)
101
—
—
(29)
7
2,516
(1,081)
(27)
—
—
—
215
(52)
(108)
26
—
—
—
—
35
(294)
(1,102)
376
—
—
42
(4)
—
—
24
(6)
—
—
(35)
(12)
(3,366)
975
(33)
13
(57)
—
—
—
—
—
—
—
—
—
—
$ 3,618
$ 3.41
—
—
—
$3,438
$ 3.25
—
—
—
$ 3,250
$ 3.11
—
—
27
$ 3,128
$ 3.07
47
9
284
$ 3,017
$ 3.02
(1) 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) a $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, disposition, and integration 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. Net income for the year ended December 31, 2018
includes: (i) a net combined $249 million pre-tax gain ($93 million after-tax loss) on the sales of Elizabethtown Gas, Elkton Gas, Florida City Gas, and Pivotal Home
Solutions, including a related impairment charge; (ii) a $119 million pre-tax ($89 million after-tax) impairment charge associated with the sales of Plants Stanton and
Oleander; and (iii) $95 million pre tax ($77 million after tax) of other acquisition, disposition, and integration costs. Net income for the year ended December 31, 2017
includes costs related to the acquisition and integration of Southern Company Gas and costs related to the dispositions of Elizabethtown Gas and Elkton Gas.
(2) Net income for the years ended December 31, 2021, 2020, and 2018 includes aggregate charges of $1.7 billion pre tax ($1.3 billion after tax), $325 million pre tax
($242 million after tax), and $1.1 billion pre tax ($0.8 billion after tax), respectively, for estimated probable losses associated with Georgia Power’s construction of
Plant Vogtle Units 3 and 4. Net income for all periods presented includes charges (net of salvage proceeds), associated legal expenses (net of insurance recoveries),
and tax impacts related to Mississippi Power’s construction and abandonment of the 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 $10 million to $20 million annually through 2025. Further charges related to Plant Vogtle Units 3 and 4
may occur; however, the amount and timing of any such charges are uncertain.
(3) Net income for the year ended December 31, 2017 includes a $32.5 million write-down ($20 million after tax) of Gulf Power’s ownership of Plant Scherer Unit 3 as the
result of a retail rate case settlement.
(4) Net income for all periods presented includes the Wholesale Gas Services business, which was sold on July 1, 2021. Presenting net income and earnings per share
excluding Wholesale Gas Services provides an additional measure of operating performance that excludes the volatility resulting from mark-to-market and lower of
weighted average cost or current market price accounting adjustments.
(5) 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 pre-tax impairment charges totaling $84 million ($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. Further impairment
charges associated with these assets are not expected.
(6) Net income for the year ended December 31, 2018 includes the settlement proceeds of Mississippi Power’s claim for lost revenue resulting from the 2010 Deepwater
Horizon oil spill. No further proceeds are expected.
(7) Net income for the years ended December 31, 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 amount and timing of any such costs are uncertain.
(8) Net income for the year ended December 31, 2017 includes AFUDC equity as a result of extending the schedule for the Kemper IGCC construction project beyond the dates
assumed when Southern Company’s 2017 earnings guidance was initially presented. AFUDC equity ceased in connection with the project’s suspension in June 2017. Net
income for the years ended December 31, 2018 and 2017 includes net tax benefits as a result of implementing the Tax Reform Legislation. During 2018, Southern Company
obtained and analyzed additional information that was not initially available or reported as provisional amounts at December 31, 2017. Southern Company believes
presentation of earnings per share excluding these adjustments provided investors with information comparable to guidance and used such measures to evaluate performance.
21
Southern Company 2021 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 the potential and expected effects of the COVID-19 pandemic, regulated rates, the strategic goals for the business,
customer and sales growth, economic conditions, cost recovery and other rate actions, projected equity ratios, current and proposed
environmental regulations and related compliance plans and estimated expenditures, 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, completion of announced acquisitions, 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 potential effects of the continued COVID-19 pandemic;
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;
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;
O the ability to complete necessary or desirable pipeline expansion or infrastructure projects, limits on pipeline capacity, and operational
interruptions to natural gas distribution and transmission activities;
O transmission constraints;
O effects of inflation;
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 Units 3 and 4 (which includes components based on new technology that only within the last few
years began initial operation in the global nuclear industry at this scale) and Plant Barry Unit 8, due to current and/or future challenges
which include, but are not limited to, changes in labor costs, availability, and productivity; challenges with management of contractors
or vendors; subcontractor performance; adverse weather conditions; shortages, delays, increased costs, or inconsistent quality of
equipment, materials, and labor; contractor or supplier delay; delays due to judicial or regulatory action; nonperformance under
construction, operating, or other agreements; operational readiness, including specialized operator training and required site safety
programs; engineering or design problems or any remediation related thereto; design and other licensing-based compliance matters,
including, for nuclear units, inspections and the timely submittal by Southern Nuclear of the ITAAC documentation for each unit and the
related investigations, reviews, and approvals by the NRC necessary to support NRC authorization to load fuel; challenges with start-
up activities, including major equipment failure, or system integration; and/or operational performance; and challenges related to the
COVID-19 pandemic;
O the ability to overcome or mitigate the current challenges at Plant Vogtle Units 3 and 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 construction projects, such as Plant Vogtle Units 3 and 4 and Plant
Barry Unit 8, including PSC approvals and FERC and NRC actions;
O under certain specified circumstances, a decision by holders of more than 10% of the ownership interests of Plant Vogtle Units 3 and
4 not to proceed with construction and the ability of other Vogtle Owners to tender a portion of their ownership interests to Georgia
Power following certain construction cost increases;
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 technologies and negative
carbon concepts;
O performance of counterparties under ongoing renewable energy partnerships and development agreements;
22
Southern Company 2021 Annual Report Cautionary Statement Regarding Forward-Looking Statements (continued)
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 electric utilities’ generating, 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 physical attacks;
O 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 replacement of LIBOR with an alternative reference rate;
O the ability of Southern Company’s electric utilities 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, 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.
Available Information
Southern Company’s Annual Report on Form 10-K for the year ended December 31, 2021 (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://ww w.sec.gov.
A copy of the Form 10-K as filed with the Securities and Exchange Commission 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 2021 and 2020
items and year-to-year comparisons between 2021 and 2020. Discussions of 2019 items and year-to-year comparisons between 2020 and
2019 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, 2020, which was filed with the SEC on February 17, 2021.
23
Southern Company 2021 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. 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 traditional electric operating company,
Southern Power, Southern Company Gas, 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 127,000 square miles in the Southeast. Southern Holdings is
an intermediate holding company subsidiary, which invests in various projects. During 2021, Southern Holdings sold or terminated three of
its leveraged lease investments and only one remains. Southern Nuclear operates and provides services to the Southern Company system’s
nuclear power plants and is currently managing construction of and developing Plant Vogtle Units 3 and 4, which are co-owned by Georgia
Power. PowerSecure develops distributed energy and resilience solutions and deploys microgrids for commercial, industrial, governmental,
and utility customers.
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 30,
2016 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.
$240
$220
$200
$180
$160
$140
$120
$100
$80
24
2016
2017
2018
2019
Southern Company
Philadelphia Utilities Index
S&P 500
2016
100
100
100
2017
102
113
122
2020
2018
99
117
116
2021
2020
150
152
181
2019
149
148
153
2021
175
180
233
Southern Company 2021 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, 2021.
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, 2021, which is included herein.
Thomas A. Fanning
Chairman, President, and Chief Executive Officer
Daniel S. Tucker
Executive Vice President and Chief Financial Officer
February 16, 2022
25
Southern Company 2021 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, 2021 and 2020, 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, 2021, 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, 2021, 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, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended
December 31, 2021, 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, 2021, 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.
26
Southern Company 2021 Annual Report Report of Independent Registered Public Accounting Firm
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current-period audit of the financial statements that were
communicated or required to be communicated to the Audit Committee of Southern Company’s Board of Directors and that (1) relate to
accounts or disclosures that are material to the financial statements and (2) involved our 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 matters below, providing separate opinions on the critical audit matters or on
the accounts or disclosures to which they relate.
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”),
which represent approximately 88% of Southern Company’s consolidated operating revenues for the year ended December 31, 2021
and 86% of its consolidated total assets at December 31, 2021, 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 impacts multiple financial
statement line items and disclosures, including, but not limited to, property, plant, and equipment; other regulatory assets; other regulatory
liabilities; other cost of removal obligations; deferred charges and credits related to income taxes; under and over recovered regulatory
clause revenues; operating revenues; operations and maintenance expenses; and depreciation and amortization.
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 by 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 that investment.
We identified the impact of rate regulation as a critical audit matter due to the significant judgments made by management to support
its assertions about impacted account balances and disclosures (e.g., asset retirement costs, property damage reserves, and remaining net
book values of retired assets) and the high degree of subjectivity involved in assessing the potential impact of future regulatory orders
on the financial statements. 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. Given that
management’s accounting judgments are based on assumptions about the outcome of future decisions by the Commissions, auditing these
judgments required specialized knowledge of accounting for rate regulation and the rate setting process due to its inherent complexities
and significant auditor judgment to evaluate management estimates and the subjectivity of audit evidence.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the uncertainty of future decisions by the Commissions 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 costs
incurred as property, plant, and equipment and deferred as regulatory assets, and (2) a refund or a future reduction in rates that should
be reported as regulatory liabilities. We also tested the effectiveness of management’s controls over the initial recognition of amounts
as property, plant, and equipment; regulatory assets or liabilities; and the monitoring and evaluation of regulatory developments that
may affect the likelihood of recovering costs in future rates or of a future reduction in rates.
O We read relevant regulatory orders issued by the Commissions for the regulated utility subsidiaries, regulatory statutes, interpretations,
procedural memorandums, filings made by intervenors, and other publicly available information to assess the likelihood of recovery in future
rates or of a future reduction in rates based on precedents of the Commissions’ treatment of similar costs under similar circumstances. We
evaluated the external information and compared it to management’s recorded regulatory asset and liability balances for completeness.
O For regulatory matters in process, we inspected filings with the Commissions by Southern Company’s regulated utility subsidiaries
and other interested parties that may impact the regulated utility subsidiaries’ future rates for any evidence that might contradict
management’s assertions.
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Southern Company 2021 Annual Report Report of Independent Registered Public Accounting Firm
O We evaluated regulatory filings for any evidence that intervenors are challenging full recovery of the cost of any capital projects.
We tested selected costs included in the capitalized project costs for completeness and accuracy.
O We obtained representation from management regarding probability of recovery for regulatory assets or refund or future reduction in rates
for regulatory liabilities to assess management’s assertion that amounts are probable 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.
Disclosure of Uncertainties – Plant Vogtle Units 3 and 4 Construction – Refer to Note 2 (Regulatory Matters –
Georgia Power – Nuclear Construction) to the financial statements
Critical Audit Matter Description
As discussed in Note 2 to the financial statements, the ultimate recovery of Georgia Power Company’s (Georgia Power) investment in the
construction of Plant Vogtle Units 3 and 4 is subject to multiple uncertainties. Such uncertainties include the potential impact of future
decisions by Georgia Power’s regulators (particularly the Georgia Public Service Commission) and potential actions by the co-owners of
the Vogtle project. In addition, Georgia Power’s ability to meet its cost and schedule forecasts could impact its ability to fully recover
its investment in the project. While the project is not subject to a cost cap, Georgia Power’s cost and schedule forecasts are subject to
numerous uncertainties which could impact cost recovery, including ongoing or future challenges with management of contractors and
vendors; subcontractor performance; supervision of craft labor and related productivity, particularly in the installation of electrical,
mechanical, and instrumentation and controls commodities, ability to attract and retain craft labor, and/or related cost escalation; and
procurement and related installation. New challenges may arise, particularly as Units 3 and 4 move into initial testing and start-up, which
may result in required engineering changes or remediation related to plant systems, structures, or components (some of which are based
on new technology that only within the last few years began initial operation in the global nuclear industry at this scale). The ongoing and
potential future challenges described above may change the projected schedule and estimated cost.
In addition, the continuing effects of the COVID-19 pandemic could further disrupt or delay construction, testing, supervisory, and support
activities at Plant Vogtle Units 3 and 4. The ultimate recovery of Georgia Power’s investment in Plant Vogtle Units 3 and 4 is subject to the
outcome of future assessments by management as well as Georgia Public Service Commission decisions in future regulatory proceedings.
After considering the significant level of uncertainty that exists regarding the future recoverability of these costs since the ultimate
outcome of these matters is subject to the outcome of future assessments by management, as well as Georgia PSC decisions in future
regulatory proceedings, Georgia Power recorded pre-tax charges to income of $1.692 billion in 2021.
In addition, management has disclosed the status, risks, and uncertainties associated with Plant Vogtle Units 3 and 4, including (1) the
status of construction; (2) the status of regulatory proceedings; (3) the status of legal actions or issues involving the co-owners of
the project; and (4) other matters which could impact the ultimate recoverability of Georgia Power’s investment in the project.
We identified as a critical audit matter the evaluation of Georgia Power’s identification and disclosure of events and uncertainties that
could impact the ultimate cost recovery of its investment in the construction of Plant Vogtle Units 3 and 4. This critical audit matter
involved significant audit effort requiring specialized industry and construction expertise, extensive knowledge of rate regulation, and
difficult and subjective judgments.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to Georgia Power’s identification and disclosure of events and uncertainties that could impact the ultimate
cost recovery of its investment in the construction of Plant Vogtle Units 3 and 4 included the following, among others:
O We tested the effectiveness of internal controls over the on-going evaluation, monitoring, and disclosure of matters related to the
construction and ultimate cost recovery of Plant Vogtle Units 3 and 4.
O We involved construction specialists to assist in our evaluation of the reasonableness of the projected in-service dates for Plant Vogtle
Units 3 and 4 and Georgia Power’s processes for on-going evaluation and monitoring of the construction schedule and to assess the
disclosures of the uncertainties impacting the ultimate cost recovery of its investment in the construction of these units.
O We attended meetings with Georgia Power and Southern Company officials, project managers (including contractors), independent
regulatory monitors, and co-owners of the project to evaluate and monitor construction status and identify cost and schedule
challenges.
O We read reports of external independent monitors employed by the Georgia Public Service Commission to monitor the status of
construction at Plant Vogtle Units 3 and 4 to evaluate the completeness of Georgia Power’s disclosure of the uncertainties impacting
the ultimate cost recovery of its investment in the construction of Plant Vogtle Units 3 and 4.
O We inquired of Georgia Power and Southern Company officials and project managers regarding the status of construction, the
construction schedule, and cost forecasts to assess the financial statement disclosures with respect to project status and potential risks
and uncertainties to the achievement of such forecasts.
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Southern Company 2021 Annual Report Report of Independent Registered Public Accounting Firm
O We inspected regulatory filings and transcripts of Georgia Public Service Commission hearings regarding the construction and cost
recovery of Plant Vogtle Units 3 and 4 to identify potential challenges to the recovery of Georgia Power’s construction costs and to
evaluate the disclosures with respect to such uncertainties.
O We inquired of Georgia Power and Southern Company management and internal and external legal counsel regarding any potential legal
actions or issues arising from project construction or issues involving the co-owners of the project.
O We monitored the status of reviews and inspections by the Nuclear Regulatory Commission to identify potential impediments to the
licensing and commercial operation of the project that could impact the ultimate cost recovery of Plant Vogtle Units 3 and 4.
O We compared the financial statement disclosures relating to this matter to the information gathered through the conduct of all our
procedures to evaluate whether there were omissions relating to significant facts or uncertainties regarding the status of construction or
other factors which could impact the ultimate cost recovery of Plant Vogtle Units 3 and 4.
O We obtained representation from management regarding disclosure of all matters related to the cost and/or status of the construction
of Plant Vogtle Units 3 and 4, including matters related to a co-owner or regulatory development, that could impact the recovery of the
related costs.
Atlanta, Georgia
February 16, 2022
We have served as Southern Company’s auditor since 2002.
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Southern Company 2021 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 and gas storage facilities.
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 the many factors that could impact the Registrants’ future results of
operations, financial condition, and liquidity.
Recent Developments
Southern Company
On October 29, 2021, Southern Company completed the sale of assets subject to a domestic leveraged lease to the lessee for $45 million.
No gain or loss was recognized on the sale. On December 13, 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). See Note 15 to the financial statements under “Southern Company” for additional information.
Alabama Power
On September 23, 2021, Alabama Power entered into an agreement to acquire all of the equity interests in Calhoun Power Company, LLC, which
owns and operates a 743-MW winter peak, simple-cycle, combustion turbine generation facility in Calhoun County, Alabama (Calhoun Generating
Station). The completion of the acquisition is subject to the satisfaction and waiver of certain conditions, including, among other customary
conditions, approval by the Alabama PSC and the FERC. On October 28, 2021, Alabama Power filed a petition for a CCN with the Alabama PSC to
procure additional generating capacity through this acquisition. The ultimate outcome of this matter cannot be determined at this time.
During 2021, Alabama Power continued construction of Plant Barry Unit 8. At December 31, 2021, associated project expenditures included
in CWIP totaled approximately $304 million.
For the year ended December 31, 2021, Alabama Power’s weighted common equity return exceeded 6.15%, resulting in Alabama Power
establishing a current regulatory liability of $181 million. In accordance with an Alabama PSC order issued on February 1, 2022, Alabama
Power will apply $126 million to reduce the Rate ECR under recovered balance and the remaining $55 million will be refunded to customers
through bill credits in July 2022.
See Note 2 to the financial statements under “Alabama Power” for additional information.
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Georgia Power
Plant Vogtle Units 3 and 4 Construction and Start-Up Status
Construction continues on Plant Vogtle Units 3 and 4 (with electric generating capacity of approximately 1,100 MWs each), in which
Georgia Power holds a 45.7% ownership interest. Georgia Power’s share of the total project capital cost forecast to complete Plant Vogtle
Units 3 and 4, including contingency, through the end of the first quarter 2023 and the fourth quarter 2023, respectively, is $10.4 billion.
Georgia Power estimates the productivity impacts of the COVID-19 pandemic have consumed approximately three to four months of
schedule margin previously embedded in the site work plan for Unit 3 and Unit 4. The continuing effects of the COVID-19 pandemic could
further disrupt or delay construction and testing activities at Plant Vogtle Units 3 and 4.
During 2021, Southern Nuclear performed additional construction remediation work necessary to ensure quality and design standards
are met and support system turnovers necessary for Unit 3 hot functional testing, which was completed in July 2021, and fuel load. As
a result of Unit 3 challenges including, but not limited to, construction productivity, construction remediation work, the pace of system
turnovers, spent fuel pool repairs, and the timeframe and duration for hot functional and other testing, at the end of each of the second
and third quarters 2021, Southern Nuclear further extended certain milestone dates, including fuel load for Unit 3, from those established
in January 2021. Through the fourth quarter 2021, the project continued to face these and other challenges related to the completion of
documentation, including inspection records, necessary to submit the remaining ITAACs and begin fuel load. As a result, at the end of the
fourth quarter 2021, Southern Nuclear further extended certain milestone dates, including fuel load for Unit 3, from those established at
the end of the third quarter 2021. The site work plan currently targets fuel load for Unit 3 in the second quarter 2022 and an in-service
date during the third quarter 2022 and primarily depends on significant improvements in overall construction productivity and production
levels, the volume of construction remediation work, the pace of system and area turnovers, and the progression of startup and other
testing. As the site work plan includes minimal margin to these milestone dates, an in-service date during the fourth quarter 2022 or the
first quarter 2023 for Unit 3 is projected, although any further delays could result in a later in-service date.
As the result of productivity challenges and temporarily diverting some Unit 4 craft and support resources to Unit 3 construction efforts,
at the end of each of the second and third quarters 2021, Southern Nuclear also further extended milestone dates for Unit 4 from those
established in January 2021. The temporary diversion of Unit 4 resources to support Unit 3 has continued into the first quarter 2022;
therefore, at the end of the fourth quarter 2021, Southern Nuclear further extended milestone dates for Unit 4 from those established
at the end of the third quarter 2021. The site work plan targets an in-service date during the first quarter 2023 for Unit 4 and primarily
depends on overall construction productivity and production levels significantly improving as well as appropriate levels of craft laborers,
particularly electricians and pipefitters, being added and maintained. As the site work plan includes minimal margin to the milestone dates,
an in-service date during the third or fourth quarter 2023 for Unit 4 is projected, although any further delays could result in a later in-
service date.
The latest schedule extension triggers the requirement that the holders of at least 90% of the ownership interests in Plant Vogtle Units 3
and 4 must vote to continue construction by March 8, 2022. Georgia Power has voted to continue construction. In addition, if the holders
of at least 90% of the ownership interests of Plant Vogtle Units 3 and 4 do not vote to continue construction, the DOE may require
Georgia Power to prepay all outstanding borrowings under the FFB Credit Facilities over a period of five years. See Note 8 to the financial
statements under “Long-term Debt – DOE Loan Guarantee Borrowings” for additional information.
During 2021, established construction contingency and additional costs totaling $1.3 billion were assigned to the base capital cost
forecast for costs primarily associated with schedule extensions, construction productivity, the pace of system turnovers, and support
resources for Units 3 and 4. Georgia Power also increased its total capital cost forecast as of December 31, 2021 by $99 million to replenish
construction contingency.
After considering the significant level of uncertainty that exists regarding the future recoverability of these costs since the ultimate
outcome of these matters is subject to the outcome of future assessments by management, as well as Georgia PSC decisions in future
regulatory proceedings, Georgia Power recorded pre-tax charges to income in the first quarter 2021, the second quarter 2021, the third
quarter 2021, and the fourth quarter 2021 of $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), respectively, for the increases in the total project capital cost forecast.
Georgia Power may request the Georgia PSC to evaluate those expenditures for rate recovery during the prudence review following the
Unit 4 fuel load pursuant to the twenty-fourth VCM stipulation described in Note 2 to the financial statements under “Georgia Power –
Nuclear Construction – Regulatory Matters.” In addition, Georgia Power recorded a pre-tax charge to income in the fourth quarter 2021
of approximately $440 million ($328 million after tax), and may be required to record additional pre-tax charges to income of up to
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
$460 million, associated with the cost-sharing and tender provisions of the joint ownership agreements based on the current project
capital cost forecast. The incremental costs associated with these provisions will not be recovered from retail customers. See Note 2 to
the financial statements under “Georgia Power – Nuclear Construction – Joint Owner Contracts” for additional information.
The ultimate impact of the COVID-19 pandemic and other factors on the construction schedule and budget 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 Unit 3 and Common Facilities Rate Proceeding
On November 2, 2021, the Georgia PSC approved Georgia Power’s application to adjust retail base rates to include a portion of costs
related to its investment in Plant Vogtle Unit 3 and the common facilities shared between Plant Vogtle Units 3 and 4 (Common Facilities),
as well as the related costs of operation, as modified pursuant to a stipulated agreement between Georgia Power and the staff of the
Georgia PSC. The related increase in annual retail base rates of approximately $302 million includes 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 production
tax credits, and will become effective the month after Unit 3 is placed in service. This increase is partially offset by a decrease in the NCCR
tariff of approximately $78 million that became effective January 1, 2022. See Note 2 to the financial statements under “Georgia Power –
Plant Vogtle Unit 3 and Common Facilities Rate Proceeding” for additional information.
Rate Plans
On November 18, 2021, in accordance with the terms of the 2019 ARP, the Georgia PSC approved tariff adjustments effective January 1,
2022 resulting in a net increase in annual retail base rates of $157 million. Georgia Power is required to file its next general base rate case
by July 1, 2022. See Note 2 to the financial statements under “Georgia Power – Rate Plans – 2019 ARP” for additional information.
Integrated Resource Plan
On January 31, 2022, Georgia Power filed its triennial IRP (2022 IRP), including a request to decertify and retire Plant Wansley Units 1 and
2 (926 MWs based on 53.5% ownership) by August 31, 2022; Plant Bowen Units 1 and 2 (1,400 MWs) by December 31, 2027; and 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) by December 31, 2028.
In the 2022 IRP, Georgia Power requested approval to reclassify the remaining net book value of Plant Wansley Units 1 and 2
(approximately $611 million at December 31, 2021), Plant Bowen Units 1 and 2 (approximately $937 million at December 31, 2021), and
Plant Scherer Unit 3 (approximately $612 million at December 31, 2021) and any remaining unusable materials and supplies inventories
upon each unit’s respective retirement dates to a regulatory asset, with recovery periods to be determined in future base rate cases.
The 2022 IRP also included a request for approval of the capital, operations and maintenance, and CCR ARO costs associated with ash
pond and landfill closures and post-closure care. The recovery of these costs is expected to be determined in future base rate cases.
A decision from the Georgia PSC on the 2022 IRP is expected in July 2022. The ultimate outcome of these matters cannot be determined at
this time. See Note 2 to the financial statements under “Georgia Power – Integrated Resource Plan” for additional information.
Mississippi Power
During the first half of 2021, the Mississippi PSC approved the following non-fuel rate changes related to Mississippi Power’s annual rate
filings for 2021:
O an increase in revenues related to the ad valorem tax adjustment factor of approximately $28 million annually, which became effective
with the first billing cycle of May 2021,
O an increase in revenues related to PEP of approximately $16 million annually, which became effective with the first billing cycle of April
2021 in accordance with the PEP rate schedule, and
O a decrease in revenues related to the ECO Plan of approximately $9 million annually, which became effective with the first billing cycle
of July 2021.
On September 9, 2021, the Mississippi PSC issued an order confirming the conclusion of its review of Mississippi Power’s 2021 IRP with no
deficiencies identified. 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 reflects 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.
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
In accordance with an accounting order issued by the Mississippi PSC on October 14, 2021, Mississippi Power reclassified $49 million of
retail costs associated with Hurricanes Zeta and Ida to a regulatory asset to be recovered through PEP over a period to be determined in
Mississippi Power’s 2022 PEP proceeding. In addition, on December 7, 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 to restore the property damage reserve.
On January 18, 2022, the Mississippi PSC approved Mississippi Power’s retail fuel cost recovery filing, which requested an increase in
revenues of approximately $43 million annually effective with the first billing cycle of February 2022.
See Note 2 to the financial statements under “Mississippi Power” for additional information.
Southern Power
During 2021, Southern Power completed construction of and placed in service the 118-MW Glass Sands wind facility, 73 MWs of the
88-MW Garland battery energy storage facility, and 32 MWs of the 72-MW Tranquillity battery energy storage facility. Southern Power
continues construction of the remainder of the Garland and Tranquillity battery energy storage facilities. On March 26, 2021, Southern
Power purchased a controlling membership interest in the 300-MW Deuel Harvest wind facility located in Deuel County, South Dakota
from Invenergy Renewables LLC.
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 the facilities currently under
construction, as well as other capacity and energy contracts, Southern Power’s average investment coverage ratio at December 31, 2021
was 95% through 2026 and 92% through 2031, with an average remaining contract duration of approximately 13 years.
See Note 15 to the financial statements under “Southern Power” for additional information.
Southern Company Gas
On April 28, 2021, Atlanta Gas Light filed its first Integrated Capacity and Delivery Plan (i-CDP) with the Georgia PSC, which includes
a series of ongoing and proposed pipeline safety, reliability, and growth programs for the next 10 years, as well as the required capital
investments and related costs to implement the programs. On November 18, 2021, the Georgia PSC approved an October 14, 2021 joint
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, or $5 million for 2022. The stipulation agreement also provides for $1.7 billion of total capital investment for the years
2022 through 2024.
Also on November 18, 2021, the Georgia PSC approved Atlanta Gas Light’s amended annual GRAM filing, which resulted in an annual rate
increase of $43 million effective January 1, 2022.
On September 14, 2021, the Virginia Commission approved a stipulation agreement related to Virginia Natural Gas’ June 2020 general
rate case filing, which allows 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 rate adjustments became effective
as of November 1, 2020, subject to refund, based on Virginia Natural Gas’ original request for an increase of approximately $50 million.
Refunds to customers related to the difference between the approved rates and the interim rates were completed during the fourth
quarter 2021.
On November 18, 2021, the Illinois Commission approved a $240 million annual base rate increase for Nicor Gas 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%.
See Note 2 to the financial statements under “Southern Company Gas” for additional information.
On July 1, 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). As a result of the sale, changes in state apportionment rates resulted in $85 million of additional tax
expense. See Note 15 to the financial statements under “Southern Company Gas” for additional information.
During the second and third quarters of 2021, Southern Company Gas recorded pre-tax impairment charges totaling $84 million
($67 million after tax) related to its equity method investment in the PennEast Pipeline project. On September 27, 2021, PennEast Pipeline
announced that further development of the project is no longer supported, and, as a result, all further development of the project has
ceased. See Note 7 to the financial statements under “Southern Company Gas” for additional information.
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Key Performance Indicators
In striving to achieve attractive risk-adjusted returns while providing cost-effective energy to approximately 8.7 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. See RESULTS OF OPERATIONS – “Southern Company Gas – Operating Metrics” for additional
information on Southern Company Gas’ operating metrics, including Heating Degree Days, customer count, and volumes of natural gas sold.
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 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 $2.4 billion in 2021, a decrease of $726 million, or 23.3%, from 2020.
The decrease was primarily due to a $1.0 billion increase in after-tax charges related to the construction of Plant Vogtle Units 3 and 4 and
higher non-fuel operations and maintenance costs, partially offset by an increase in natural gas revenues associated with colder weather in
the first quarter 2021 as compared to the corresponding period in 2020 and infrastructure replacement programs and base rate changes,
higher retail electric revenues primarily associated with rates and pricing and sales growth, a decrease in impairment charges and a gain on
termination related to leveraged leases at Southern Holdings, and higher wholesale electric capacity revenues. See Notes 2, 9, and 15 to
the financial statements under “Georgia Power – Nuclear Construction,” “Southern Company Leveraged Lease,” and “Southern Company,”
respectively, for additional information.
Basic EPS was $2.26 in 2021 and $2.95 in 2020. Diluted EPS, which factors in additional shares related to stock-based compensation,
was $2.24 in 2021 and $2.93 in 2020. EPS for 2021 and 2020 was negatively impacted by $0.01 and $0.03 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 $2.62 in 2021 and $2.54 in 2020. In January 2022, Southern Company declared a
quarterly dividend of 66 cents per share. For 2021, the dividend payout ratio was 116% compared to 86% for 2020.
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.
Electricity business
Gas business
Other business activities
Net Income
34
2021
2020
(in millions)
$2,247
539
(393)
$2,393
$ 3,115
590
(586)
$ 3,119
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
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
Impairment charges
Gain on dispositions, net
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 2020
2021
(in millions)
$18,300
4,010
978
109
4,809
2,953
1,062
1,692
2
(59)
15,556
2,744
179
968
427
219
2,163
15
(99)
$ 2,247
$ 1,803
1,043
179
15
559
12
38
1,367
2
(17)
3,198
(1,395)
41
(8)
112
(298)
(936)
—
(68)
$ (868)
Electric operating revenues for 2021 were $18.3 billion, reflecting a $1.8 billion, or 10.9%, increase from 2020. Details of electric operating
revenues were as follows:
Retail electric — prior year
Estimated change resulting from —
Rates and pricing
Sales growth
Weather
Fuel and other cost recovery
Retail electric — current year
Wholesale electric revenues
Other electric revenues
Other revenues
Electric operating revenues
2021
2020
(in millions)
$13,643
209
208
(74)
866
$14,852
2,455
718
275
$18,300
$13,643
1,945
672
237
$16,497
Retail electric revenues increased $1.2 billion, or 8.9%, in 2021 as compared to 2020. The significant factors driving this change are shown
in the preceding table. The increase in rates and pricing in 2021 was primarily due to an increase effective January 1, 2021 in Alabama
Power’s Rate RSE, net of a related customer refund, and increases at Georgia Power resulting from higher contributions by commercial and
industrial customers with variable demand-driven pricing, fixed residential customer bill programs, the effects of higher KWH sales on ECCR
tariff revenues, and base tariff increases in accordance with the 2019 ARP, partially offset by a decrease in Georgia Power’s NCCR tariff,
both effective January 1, 2021.
35
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Electric rates for the traditional electric operating companies include provisions to adjust billings for fluctuations in fuel costs, including the
energy component of purchased power costs. Under these provisions, fuel revenues generally equal fuel expenses, including the energy
component of PPA costs, and do not affect net income. The traditional electric operating companies each have one or more regulatory
mechanisms to recover other costs such as environmental and other compliance costs, storm damage, new plants, and PPA capacity costs.
See Note 2 to the financial statements 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 changes related to sales growth (decline) and weather.
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.
Wholesale electric revenues from power sales were as follows:
Capacity and other
Energy
Total
2021
2020
(in millions)
$ 550
1,905
$2,455
$ 476
1,469
$ 1,945
In 2021, wholesale electric revenues increased $510 million, or 26.2%, as compared to 2020 due to increases of $436 million in energy
revenues and $74 million in capacity revenues. Energy revenues increased $292 million at Southern Power primarily from a $247 million
net increase in the price of energy and a $45 million increase in the volume of KWHs sold. Energy revenues increased $144 million at the
traditional electric operating companies primarily due to higher energy prices. The increase in capacity revenues primarily resulted from a
power sales agreement at Alabama Power that began in September 2020 and a net increase in natural gas PPAs at Southern Power.
Other Electric Revenues
Other electric revenues increased $46 million, or 6.8%, in 2021 as compared to 2020. The increase was primarily due to increases of
$28 million in transmission revenues primarily related to new PPAs at Southern Power and increased open access transmission tariff
sales at Alabama Power, $27 million in customer fees largely resulting from the COVID-19 pandemic-related temporary suspensions of
disconnections and late fees in 2020 for the traditional electric operating companies, $11 million from outdoor lighting sales at Georgia
Power, and $10 million in cogeneration steam revenue associated with higher natural gas prices at Alabama Power, partially offset by a
$26 million decrease in pole attachment revenues at Georgia Power.
36
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Energy Sales
Changes in revenues are influenced heavily by the change in the volume of energy sold from year to year. KWH sales for 2021 and the
percent change from 2020 were as follows:
Residential
Commercial
Industrial
Other
Total retail
Wholesale
Total energy sales
Total
KWHs
(in billions)
47.4
46.7
48.7
0.6
143.4
50.0
193.4
2021
Total KWH
Percent
Change
Weather-
Adjusted Percent
Change(*)
(0.2)%
2.7
3.7
(5.1)
2.0
9.5
3.8%
0.5%
3.2
3.7
(5.1)
2.4%
(*) 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.
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 increased 3.4 billion KWHs in 2021 as compared to 2020. Weather-adjusted residential usage
increased primarily due to customer growth, largely offset by decreased customer usage resulting from shelter-in-place orders in effect
during 2020. Weather-adjusted commercial and industrial usage increased primarily due to the negative impacts of the COVID-19
pandemic on energy sales being more severe in 2020.
See “Electric Operating Revenues” above for a discussion of significant changes in wholesale revenues related to changes in price and
KWH sales.
37
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Other Revenues
Other revenues increased $38 million, or 16.0%, in 2021 as compared to 2020. The increase was primarily due to increases in unregulated
sales of products and services of $29 million at Alabama Power and $9 million 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)
Total purchased power (in billions of KWHs)
Sources of generation (percent) —
Gas
Coal
Nuclear
Hydro
Wind, Solar, and Other
Cost of fuel, generated (in cents per net KWH) —
Gas(a)
Coal
Nuclear
Average cost of fuel, generated (in cents per net KWH)(a)
Average cost of purchased power (in cents per net KWH)(b)
2021
179
18
48
22
18
4
8
3.07
2.85
0.75
2.55
5.85
2020
174
18
52
18
18
4
8
2.03
2.91
0.78
1.96
4.65
(a) Excludes Central Alabama Generating Station KWHs and associated cost of fuel as its fuel is provided by the purchaser under a power sales agreement.
See Note 15 to the financial statements under “Alabama Power” for additional information.
(b) Average cost of purchased power includes fuel purchased by the Southern Company system for tolling agreements where power is generated by the provider.
In 2021, total fuel and purchased power expenses were $5.0 billion, an increase of $1.2 billion, or 32.4%, as compared to 2020. The
increase was primarily the result of a $1.1 billion increase in the average cost of fuel generated and purchased and a $170 million increase
in the volume of KWHs generated and purchased.
Fuel and purchased power energy transactions at the traditional electric operating companies are generally offset by fuel revenues and
do not have a significant impact on net income. See Note 2 to the financial statements 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 2021, fuel expense was $4.0 billion, an increase of $1.0 billion, or 35.2%, as compared to 2020. The increase was primarily due to a 51.2%
increase in the average cost of natural gas per KWH generated, a 25.7% increase in the volume of KWHs generated by coal, and a 12.2%
decrease in the volume of KWHs generated by hydro, partially offset by a 4.9% decrease in the volume of KWHs generated by natural gas.
Purchased Power
In 2021, purchased power expense was $978 million, an increase of $179 million, or 22.4%, as compared to 2020. The increase was
primarily due to a 25.8% increase in the average cost per KWH purchased primarily due to higher natural gas prices.
Energy purchases will vary depending on demand for energy within the Southern Company system’s electric service territory, the market
prices of wholesale energy as compared to the cost of the Southern Company system’s generation, and the availability of the Southern
Company system’s generation.
Cost of Other Sales
Cost of other sales increased $15 million, or 16.0%, in 2021 as compared to 2020 primarily due to an increase in unregulated power
delivery construction and maintenance projects at Georgia Power.
Other Operations and Maintenance Expenses
Other operations and maintenance expenses increased $559 million, or 13.2%, in 2021 as compared to 2020. A portion of the increase in
2021 compared to 2020 reflects cost containment activities implemented to help offset the effects of the recessionary economy resulting
38
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
from the beginning of the COVID-19 pandemic. The increase was primarily associated with increases of $174 million in transmission
and distribution expenses, including $37 million of reliability NDR credits applied in 2020 at Alabama Power, $133 million in scheduled
generation outage and maintenance expenses, and $63 million in compensation and benefit expenses, as well as a $40 million loss on
sales-type leases associated with PPAs at Southern Power’s Garland and Tranquillity battery energy storage facilities. Also contributing
to the increase was a $19 million increase in compliance and environmental expenses at the traditional electric operating companies and
an $18 million decrease in nuclear property insurance refunds at Alabama Power and Georgia Power. See Notes 2 and 9 to the financial
statements under “Alabama Power – Rate NDR” and “Lessor,” respectively, for additional information.
Depreciation and Amortization
Depreciation and amortization increased $12 million, or 0.4%, in 2021 as compared to 2020. The increase was due to an increase of
$111 million in depreciation associated with additional plant in service, partially offset by a net decrease of $90 million in amortization of
regulatory assets primarily associated with CCR AROs under the terms of Georgia Power’s 2019 ARP. See Note 2 to the financial statements
under “Georgia Power – Rate Plans” for additional information.
Taxes Other Than Income Taxes
Taxes other than income taxes increased $38 million, or 3.7%, in 2021 as compared to 2020. The increase primarily reflects a $25 million
increase in municipal franchise fees at Georgia Power and a $21 million increase in property taxes primarily resulting from higher assessed
values, partially offset by a $14 million decrease in utility license taxes at Alabama Power.
Estimated Loss on Plant Vogtle Units 3 and 4
Estimated probable loss on Plant Vogtle Units 3 and 4 increased $1.4 billion in 2021 as compared to 2020. The losses in each year were
recorded to reflect Georgia Power’s revised total project capital cost forecast to complete construction and start-up of Plant Vogtle Units 3
and 4. See Note 2 to the financial statements under “Georgia Power – Nuclear Construction” for additional information.
Gain on Dispositions, Net
Gain on dispositions, net increased $17 million, or 40.5%, in 2021 as compared to 2020. The increase primarily reflects $41 million in gains
at Southern Power primarily due to contributions of wind turbine equipment to various equity method investments in the first quarter
2021 and $14 million in gains at Alabama Power primarily from property sales, partially offset by a $39 million gain at Southern Power
related to the sale of Plant Mankato in the first quarter 2020. See Notes 7 and 15 to the financial statements under “Southern Power” for
additional information.
Allowance for Equity Funds Used During Construction
Allowance for equity funds used during construction increased $41 million, or 29.7%, in 2021 as compared to 2020. The increase was
primarily associated with Georgia Power’s construction of Plant Vogtle Units 3 and 4. See Note 2 to the financial statements under
“Georgia Power – Nuclear Construction – Regulatory Matters” for additional information.
Interest Expense, Net of Amounts Capitalized
Interest expense, net of amounts capitalized decreased $8 million, or 0.8%, in 2021 as compared to 2020 primarily due to a decrease
of approximately $30 million due to lower interest rates at the traditional electric operating companies and an $11 million net increase
in capitalized interest, partially offset by an increase of approximately $33 million due to an increase in average outstanding long-term
borrowings. See Note 8 to the financial statements for additional information.
Other Income (Expense), Net
Other income (expense), net increased $112 million, or 35.6%, in 2021 as compared to 2020 primarily related to a $135 million increase in
non-service cost-related retirement benefits income, partially offset by a $12 million gain recorded by Southern Power in the third quarter
2020 associated with the Roserock solar facility litigation and an $8 million decrease in interest income. See Note 11 to the financial
statements for additional information.
Income Taxes
Income taxes decreased $298 million, or 57.6%, in 2021 as compared to 2020. The decrease was primarily due to lower pre-tax earnings
primarily resulting from higher charges in 2021 associated with the construction of Plant Vogtle Units 3 and 4 at Georgia Power and
changes in state apportionment methodology resulting from tax legislation enacted by the State of Alabama in February 2021 at
Southern Power, partially offset by an increase in a valuation allowance on certain state tax credit carryforwards at Georgia Power.
See Note 2 to the financial statements under “Georgia Power – Nuclear Construction” and Note 10 to the financial statements for
additional information.
39
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Net Loss Attributable to Noncontrolling Interests
Substantially all noncontrolling interests relate to renewable projects at Southern Power. Net loss attributable to noncontrolling interests
increased $68 million in 2021 as compared to 2020. The increased loss was primarily due to loss allocations to Southern Power’s partners in
the Garland and Tranquillity battery energy storage facilities, including $26 million allocated from the loss on sales-type leases. In addition,
the increased loss was due to higher HLBV loss allocations to Southern Power’s wind tax equity partners, including new partnerships
entered into during 2020 and 2021, and lower income allocations to Southern Power’s solar equity partners, totaling $29 million. See Notes
9 and 15 to the financial statements under “Lessor” and “Southern Power,” respectively, for additional information.
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, wholesale gas services (until the sale of Sequent on July 1, 2021), 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
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
Seasonality of Results
Increase
(Decrease)
from 2020
2021
(in millions)
$4,380
1,619
1,072
536
225
(127)
3,325
1,055
50
238
(53)
275
$ 946
647
106
36
19
(105)
703
243
(91)
7
(94)
102
$ 539
$ (51)
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.
Prior to the sale of Sequent, wholesale gas services’ operating revenues were occasionally impacted due to peak usage by power generators
in response to summer energy demands. Southern Company Gas’ base operating expenses, excluding cost of natural gas, bad debt expense,
and certain incentive compensation costs, are incurred relatively equally over any given year. Thus, operating results can vary significantly
from quarter to quarter as a result of seasonality. For 2021, the percentage of operating revenues and net income generated during the
Heating Season (January through March and November through December) were 70% and 102%, respectively. For 2020, the percentage of
operating revenues and net income generated during the Heating Season were 68% and 86%, respectively.
Operating Revenues
Operating revenues in 2021 were $4.4 billion, reflecting a $946 million, or 27.5%, increase compared to 2020. 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
Wholesale gas services
Other
Operating revenues – current year
40
2021
(in millions)
$3,434
146
675
114
11
$4,380
Southern Company 2021 Annual Report
Management’s Discussion and Analysis of Financial Condition and Results of Operations
Revenues at the natural gas distribution utilities increased in 2021 compared to 2020 due to rate increases and continued investment in
infrastructure replacement. See Note 2 to the financial statements under “Southern Company Gas” for additional information.
Revenues associated with gas costs and other cost recovery increased in 2021 compared to 2020 primarily due to higher natural gas
cost recovery as a result of higher volumes of natural gas sold and an increase in natural gas prices. 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 wholesale gas services increased in 2021 primarily due to higher volumes of natural gas sold and higher commercial
activities as a result of Winter Storm Uri, partially offset by derivative losses, all prior to the sale of Sequent. See Note 15 to the financial
statements under “Southern Company Gas” for additional information.
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 charge their 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.
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. Therefore, gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural
gas and do not affect net income from the natural gas distribution utilities. Cost of natural gas at the natural gas distribution utilities
represented 86.3% of the total cost of natural gas for 2021.
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, adjustments to reduce the value of inventories to market value, if
applicable, and gains and losses associated with certain derivatives.
Cost of natural gas was $1.6 billion, an increase of $647 million, or 66.6%, in 2021 compared to 2020, which reflects higher gas cost
recovery in 2021 as a result of higher volumes sold and a 91.2% increase in natural gas prices compared to 2020.
Other Operations and Maintenance Expenses
Other operations and maintenance expenses increased $106 million, or 11.0%, in 2021 compared to 2020. The increase was primarily due
to increases of $60 million in compensation expenses, $30 million of which was at Sequent, $10 million in facility costs, and $10 million in
bad debt expense, which is passed through directly to customers and has no impact on net income.
Depreciation and Amortization
Depreciation and amortization increased $36 million, or 7.2%, in 2021 compared to 2020. 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 increased $19 million, or 9.2%, in 2021 compared to 2020. The increase was primarily due to a $15 million
increase in revenue tax expenses as a result of higher natural gas revenues at Nicor Gas, which are passed through directly to customers
and have no impact on net income.
Gain on Dispositions, Net
Gain on dispositions, net increased $105 million in 2021 compared to 2020. In 2021, Southern Company Gas recorded a $121 million gain on the
sale of Sequent, as well as an additional $5 million gain from the sale of Pivotal LNG. In 2020, Southern Company Gas recorded a $22 million gain
on the sale of Jefferson Island. See Note 15 to the financial statements under “Southern Company Gas” for additional information.
Earnings from Equity Method Investments
Earnings from equity method investments decreased $91 million, or 64.5%, in 2021 compared to 2020. The decrease was primarily due
to impairment charges in 2021 totaling $84 million related to the PennEast Pipeline project. See Note 7 to the financial statements under
“Southern Company Gas” for additional information.
41
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Other Income (Expense), Net
Other income (expense), net decreased $94 million in 2021 compared to 2020. The decrease was largely due to $101 million in charitable
contributions by Sequent prior to its sale.
Income Taxes
Income taxes increased $102 million, or 59.0%, in 2021 compared to 2020. The increase was primarily due to $114 million in additional tax
expense resulting from the sale of Sequent, including changes in state tax apportionment rates, and higher pre-tax earnings at the natural
gas distribution utilities, partially offset by $18 million of tax benefit resulting from the PennEast Pipeline project impairment charges in
the second and third quarters of 2021. See Notes 7 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
Gain on dispositions, net
Total operating expenses
Operating income (loss)
Earnings from equity method investments
Interest expense
Impairment of leveraged leases
Other income (expense), net
Income taxes (benefit)
Net loss
Operating Revenues
Increase
(Decrease)
from 2020
2021
(in millions)
$ 433
249
207
75
4
—
535
(102)
26
631
7
94
(227)
$(393)
$ (11)
15
11
(2)
—
1
25
(36)
14
17
(199)
103
70
$ 193
Southern Company’s operating revenues for these other business activities decreased $11 million, or 2.5%, in 2021 as compared to 2020
primarily due to a decrease at Southern Linc related to a contract for the design and construction of a fiber optic system completed in 2020.
Cost of Other Sales
Cost of other sales for these other business activities increased $15 million, or 6.4%, in 2021 as compared to 2020 primarily due to
distributed infrastructure projects at PowerSecure.
Other Operations and Maintenance Expenses
Other operations and maintenance expenses for these other business activities increased $11 million, or 5.6%, in 2021 as compared to
2020. The increase was primarily due to a $16 million increase at the parent company primarily related to director compensation expenses
and an $11 million increase at PowerSecure primarily associated with higher bad debt expense, partially offset by a $17 million decrease at
Southern Linc primarily related to the design and construction of a fiber optic system completed in 2020.
Earnings from Equity Method Investments
Earnings from equity method investments for these other business activities increased $14 million in 2021 as compared to 2020 primarily
due to an increase in investment income at Southern Holdings.
42
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Interest Expense
Interest expense for these other business activities increased $17 million, or 2.8%, in 2021 as compared to 2020 primarily due to an
increase of approximately $64 million related to higher average outstanding long-term borrowings, partially offset by decreases of
approximately $34 million due to lower interest rates and $6 million due to a reduction in losses associated with the extinguishment of
debt at the parent company. See Note 8 to the financial statements for additional information.
Impairment of Leveraged Leases
Impairment charges related to leveraged lease investments at Southern Holdings decreased $199 million, or 96.6%, in 2021 as compared to
2020. See Notes 9 and 15 to the financial statements under “Southern Company Leveraged Lease” and “Southern Company,” respectively,
for additional information.
Other Income (Expense), Net
Other income (expense), net for these other business activities increased $103 million in 2021 as compared to 2020 primarily due to a
$93 million pre-tax gain ($99 million gain after tax) recorded at Southern Holdings in 2021 related to the termination of leveraged leases
and a $12 million decrease in charitable donations 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 decreased $70 million, or 23.6%, in 2021 as compared to 2020 primarily due
to the tax impacts related to the 2020 charges associated with leveraged lease investments and the 2021 leveraged lease dispositions at
Southern Holdings, partially offset by lower pre-tax earnings at the parent company. See Notes 9, 10, and 15 to the financial statements
under “Southern Company Leveraged Lease,” “Effective Tax Rate,” and “Southern Company,” respectively, for additional information.
FUTURE EARNINGS POTENTIAL
General
Prices for electric service provided by the traditional electric operating companies and natural gas distributed 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 disposition activities described
in Note 15 to the financial statements have reduced earnings for the applicable Registrants. 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 trend of reduced electricity usage per customer, especially in
residential and commercial markets. For Georgia Power, completing construction of Plant Vogtle Units 3 and 4 and the related cost recovery
proceedings is another major factor.
Earnings in the electricity business will also depend upon maintaining and growing sales, considering, among other things, the adoption
and/or penetration rates of increasingly energy-efficient technologies and increasing volumes of electronic commerce transactions, which
could contribute to a net reduction in customer usage.
Global and U.S. economic conditions have been significantly affected by a series of demand and supply shocks that caused a global
and national economic recession in 2020. Most prominently, the COVID-19 pandemic has negatively impacted global supply chains
and business operations as suppliers continue to experience difficulties keeping up with strong demand for factory goods, which is
being driven by low business inventories. In addition, rising inflation in 2021 and 2022 has resulted in increasing costs for many goods
43
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
and services. The combination of rising inoculation rates in the U.S. population and the federal COVID-19 relief package contributed to
increased economic recovery in 2021; however, fiscal support of business and personal incomes is declining. The drivers, speed, and depth
of the 2020 economic contraction were unprecedented and have reduced energy demand across the Southern Company system’s service
territory, primarily in the commercial and industrial classes. Retail electric revenues attributable to changes in sales increased in 2021
when compared to 2020 primarily due to the normalization of economic activity; however, retail electric sales continued to be negatively
impacted by the COVID-19 pandemic when compared to pre-pandemic trends. Recovery is expected to continue in 2022, but the impacts
of new COVID-19 variants, as well as responses to the COVID-19 pandemic by both customers and governments, could significantly
affect the pace of recovery. The ultimate extent of the negative impact on revenues depends on the depth and duration of the economic
contraction in the Southern Company system’s service territory and cannot be determined at this time. See RESULTS OF OPERATIONS
herein for information on COVID-19-related impacts on energy demand in the Southern Company system’s service territory during 2021.
The level of future earnings for Southern Power’s competitive wholesale electric business depends on numerous factors including the
parameters of the wholesale market and the efficient operation of its wholesale generating assets; Southern Power’s ability to execute its
growth strategy through the development or acquisition of renewable facilities and other energy projects while containing costs; regulatory
matters; customer creditworthiness; total electric generating capacity available in Southern Power’s market areas; Southern Power’s ability
to successfully remarket capacity as current contracts expire; renewable portfolio standards; availability of federal and state ITCs 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, Note 10 to the financial statements, and Note 15 to the financial
statements under “Southern Power” 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 resilience, natural gas, and capital
expenditures, including expanding and improving the natural gas distribution systems; the completion and subsequent operation of
ongoing infrastructure and other construction projects; customer creditworthiness; certain city-wide bans on the use of natural gas in
new construction; and Southern Company Gas’ ability to re-contract storage rates at favorable prices. The volatility of natural gas prices
has an impact on Southern Company Gas’ customer rates, its long-term competitive position against other energy sources, and the ability
of Southern Company Gas’ gas marketing services business to capture value from locational and seasonal spreads. Additionally, changes
in commodity prices, primarily driven by tight gas supplies and diminished gas production, subject a portion of Southern Company Gas’
operations to earnings variability. Additional economic factors may contribute to this environment. If current economic conditions continue
to improve, the demand for natural gas may increase, which may cause natural gas prices to rise and drive higher volatility in the natural
gas markets on a longer-term basis. Alternatively, a significant drop in oil and natural gas prices could lead to a consolidation of natural gas
producers or reduced levels of natural gas production.
Earnings for both the electricity and natural gas businesses are subject to a variety of other factors. These factors include weather,
competition, developing new and maintaining existing energy contracts and associated load requirements with wholesale customers,
energy conservation practiced by customers, the use of alternative energy sources by customers, government incentives to reduce overall
energy usage, the prices of electricity and natural gas, 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 full requirements cost-based electric tariffs which are subject to regulation by the FERC. The contracts with
these wholesale customers represented 14.3% of Mississippi Power’s total operating revenues in 2021 and are generally subject to 10-year
rolling cancellation notices. Historically, these wholesale customers have acted as a group and any changes in contractual relationships for
one customer are likely to be followed by the other wholesale customers.
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.
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
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 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 the ability to continue
recovering the related costs, through rates for the traditional electric operating companies and the natural gas distribution utilities or
through long-term wholesale agreements for the traditional electric operating companies and Southern Power.
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 with 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 operating any type of 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
2026 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
2022
2023
2024
2025
2026
Total
(in millions)
$98
49
37
12
$111
35
75
1
$146
50
91
5
$72
33
34
5
$58
28
25
5
$ 485
195
262
28
These estimates do not include any costs associated with potential regulation of GHG emissions. See “Global Climate Issues” 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.
45
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Environmental Laws and Regulations
Air Quality
The Southern Company system reduced SO2 and NOX air emissions by 99% and 93%, respectively, from 1990 to 2020. The Southern
Company system reduced mercury air emissions by 98% from 2005 to 2020.
The EPA finalized regional haze regulations in 2005 and 2017. These regulations require states and various federal agencies to develop
and implement plans to reduce pollutants that impair visibility and demonstrate reasonable progress toward the goal of restoring natural
visibility conditions in certain areas, including national parks and wilderness areas. States were required to submit state implementation
plans for the second 10-year planning period (2018 through 2028) by July 31, 2021; however, plans have not yet been submitted by the
applicable states in the Southern Company system’s service territory. These plans could require further reductions in particulate matter,
SO2, and/or NOX, which could result in increased compliance costs at affected electric generating units.
Water Quality
In 2014, the EPA finalized requirements under Section 316(b) of the Clean Water Act (CWA) to regulate cooling water intake structures
(CWIS) to minimize their effects on fish and other aquatic life at existing power plants. The regulation requires plant-specific studies to
determine applicable CWIS changes to protect organisms. The results of these plant-specific studies, which are ongoing within the Southern
Company system, are being submitted with each plant’s next National Pollutant Discharge Elimination System (NPDES) permit cycle. The
Southern Company system anticipates applicable CWIS changes may include fish-friendly CWIS screens with fish return systems and minor
additions of monitoring equipment at certain plants. The impact of this rule will depend on the outcome of these plant-specific studies,
any additional protective measures required to be incorporated into each plant’s NPDES permit based on site-specific factors, and the
outcome of any legal challenges.
In October 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 extends the latest applicability date
for both discharges to December 31, 2025. The ELG Reconsideration Rule also updates the voluntary incentive program and provides new
subcategories for low utilization electric generating units and electric generating units that will permanently cease coal combustion by
2028. As required by the ELG Reconsideration Rule, on October 13, 2021, Alabama Power and Georgia Power each submitted initial notices
of planned participation (NOPP) for applicable units seeking to qualify for these subcategories.
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). These
plans are expected to be completed on or before the compliance date of December 31, 2028. The NOPP submittals are subject to the
review of the ADEM. Retirement of Plant Barry Unit 5 could occur as early as 2023, subject to completion of the acquisition of the Calhoun
Generating Station and certain operating conditions. See Notes 2 and 7 to the financial statements under “Alabama Power – Certificates of
Convenience and Necessity” and “SEGCO,” respectively, for additional information.
The 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 $1.5 billion (excluding capitalized asset retirement costs which are recovered through Rate CNP Compliance)
at December 31, 2021. 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), 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 intends 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.
The units for which Georgia Power has indicated early retirement plans have net book values totaling approximately $2.2 billion (excluding
capitalized asset retirement costs which are recovered through the ECCR tariff) at December 31, 2021. A final decision regarding the
future operation of Georgia Power’s impacted units and the timing of any retirements are subject to review by the Georgia PSC as a part
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
of Georgia Power’s 2022 IRP proceeding. See Note 2 to the financial statements under “Georgia Power – Integrated Resource Plan” for
additional information.
The ultimate outcome of these matters cannot be determined at this time.
The ELG Reconsideration Rule is expected to require capital expenditures and increased operational costs for the traditional electric
operating companies and SEGCO. However, the ultimate impact of the ELG Reconsideration Rule will depend on the Southern Company
system’s final assessment of compliance options, the incorporation of these assessments into each of the traditional electric operating
company’s IRP process, the incorporation of these new requirements into each plant’s NPDES permit, and the outcome of legal challenges.
The ELG Reconsideration Rule has been challenged by several environmental organizations and the cases have been consolidated in the
U.S. Court of Appeals for the Fourth Circuit. The case is being held in abeyance while the EPA undertakes a new rulemaking to revise the
ELG Reconsideration Rule. A proposed rule is expected in the fall of 2022. Any revisions could require changes in the traditional electric
operating companies’ compliance strategies.
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. The State of
Mississippi has not developed a state CCR permit program.
The Holistic Approach to Closure: Part A rule, finalized in August 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. On January 11, 2022, the EPA proposed determinations on deadline extension requests for other non-
affiliated facilities, which reflected its positions on a variety of CCR Rule compliance requirements including closure standards, groundwater
monitoring, and corrective action. The traditional electric operating companies are in the process of reviewing these determinations to
determine how the EPA’s current positions may impact their closure plans and groundwater monitoring efforts. The ultimate impact of the
EPA’s announced positions on the traditional electric operating companies cannot be determined at this time, but may be material.
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
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,” Note 2 to the financial
statements under “Georgia Power – Rate Plans,” and Note 6 to the financial statements for additional information.
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.
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Global Climate Issues
In 2019, the EPA published the final Affordable Clean Energy rule (ACE Rule), which would have required states to develop unit-specific CO2
emission rate standards for existing coal-fired units based on heat-rate efficiency improvements. On January 19, 2021, the U.S. Court of
Appeals for the District of Columbia Circuit vacated and remanded the ACE Rule back to the EPA. On October 29, 2021, the U.S. Supreme
Court granted four petitions for writs of certiorari asking the court to review the District of Columbia Circuit’s decision. The U.S. Supreme
Court’s review will focus on the extent of the EPA’s authority to regulate GHG emissions from the power sector under Section 111(d) of the
Clean Air Act.
On February 19, 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. On April 22, 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 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 22% coal and 48% natural gas in 2021. This transition has been supported in
part by the Southern Company system retiring over 5,600 MWs of coal-fired generating capacity since 2010 and converting over 3,400
MWs of generating capacity from coal to natural gas since 2015, as well as constructing and/or acquiring over 11,000 MWs of renewable
resource capacity since 2010. 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’ 2020 and preliminary 2021 GHG emissions based on equity share of facilities:
Southern Company(*)
Alabama Power(*)
Georgia Power
Mississippi Power
Southern Power
Southern Company Gas(*)
Preliminary 2021
2020
(in million metric tons of CO2 equivalent)
82
34
23
8
11
1
75
28
21
8
12
1
(*) 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.
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 2021 emissions, the Southern Company system
has achieved an estimated GHG emission reduction of 47% since 2007. In 2020, the COVID-19 pandemic resulted in reduced electricity
usage by customers, which led to a higher than expected decline in GHG emissions. In 2021, increased customer demand combined with
increased utilization of the coal generating fleet due to higher natural gas prices resulted in an increase in GHG emissions from 2020
levels. Southern Company system management expects to achieve sustained GHG emissions reductions of at least 50% as early as 2025.
Southern Company system management, working with applicable regulators, plans to transition its generating fleet 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; 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.
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.
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
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 intends to continue its strategy of developing and constructing new electric generating
facilities, expanding and improving the electric transmission and electric and natural gas distribution systems, and undertaking projects to
comply with environmental laws and regulations.
For the traditional electric operating companies, major generation construction projects are subject to state PSC approval in order to be
included in retail rates. The largest construction project currently underway in the Southern Company system is Plant Vogtle Units 3 and
4. See Note 2 to the financial statements under “Georgia Power – Nuclear Construction” for additional information. Also see Note 2 to
the financial statements under “Alabama Power – Certificates of Convenience and Necessity” for information regarding Alabama Power’s
construction of Plant Barry Unit 8.
See Note 15 to the financial statements under “Southern Power” for information about costs relating to Southern Power’s construction of
renewable energy facilities.
Southern Company Gas is engaged in various infrastructure improvement programs designed to update or expand the natural gas
distribution systems of the natural gas distribution utilities to improve reliability and meet operational flexibility and growth. The natural
gas distribution utilities recover their investment and a return associated with these infrastructure programs through their regulated rates.
See Note 2 to the financial statements 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.
Southern Power is working to maintain and expand its share of the wholesale markets. During 2021, Southern Power continued to
be successful in remarketing up to 2,025 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.
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Solar and Wind
Southern Power’s electricity sales from solar and wind generating facilities are also primarily through long-term PPAs; however, these 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 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 renewable energy credits.
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
The Tax Reform Legislation, as modified by the 2021 Consolidated Appropriations Act signed into law in December 2020, retained solar
energy incentives as described in the following table:
ITC Percentage
30%
26%
22%
Date Project Commenced Construction
Prior to December 31, 2019
From 2020 through 2022
During 2023
A permanent 10% ITC will remain for projects that commence construction on or after January 1, 2024 and any projects placed in service
after December 31, 2025, regardless of when construction began.
In addition, various tax legislation has retained or extended wind energy incentives as described in the following table:
PTC Percentage
100%
80%
60%
40%
60%
0%
Year Project Commenced Construction
2016
2017
2018
2019
2020 or 2021
2022 and after
Southern Company has received ITCs and PTCs in connection with investments in solar, wind, fuel cell facilities, 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, 2021, Southern
Company and Southern Power had approximately $1.2 billion and $0.8 billion, respectively, of unutilized federal ITCs and PTCs, which are
currently expected to be fully utilized by 2024, 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 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. 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.
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
50
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
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. Significant accounting policies are described in the
notes to the financial statements. In the application of these policies, certain estimates are made that may have a material impact
on the results of operations 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 the following 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.
Revenues related to regulated utility operations as a percentage of total operating revenues in 2021 for the applicable Registrants were as
follows: 88% for Southern Company, 98% for Alabama Power, 96% for Georgia Power, 99.7% for Mississippi Power, and 84% 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.
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 the Vogtle Cost Settlement Agreement, which resolved certain prudency matters in connection with
Georgia Power’s fifteenth VCM report. In 2017, the Georgia PSC approved Georgia Power’s seventeenth VCM report, which included a
recommendation to continue construction of Plant Vogtle Units 3 and 4, with Southern Nuclear serving as project manager and Bechtel
serving as the primary construction contractor, as well as a modification of the Vogtle Cost Settlement Agreement. The Georgia PSC’s
related order stated that under the modified Vogtle Cost Settlement Agreement, (i) none of the $3.3 billion of costs incurred through
December 31, 2015 should be disallowed as imprudent; (ii) the Contractor Settlement Agreement was reasonable and prudent and none
of the $0.3 billion paid pursuant to the Contractor Settlement Agreement should be disallowed from rate base on the basis of imprudence;
(iii) capital costs incurred up to $5.68 billion would be presumed to be reasonable and prudent with the burden of proof on any party
challenging such costs; (iv) Georgia Power would have the burden of proof to show that any capital costs above $5.68 billion were
prudent; (v) 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 did not represent a cost cap; and
(vi) a prudence proceeding on cost recovery will occur subsequent to achieving fuel load for Unit 4. In its order, the Georgia PSC also stated
if other conditions change and assumptions upon which Georgia Power’s seventeenth VCM report are based do not materialize, the Georgia
PSC reserved the right to reconsider the decision to continue construction.
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
As of December 31, 2021, Georgia Power revised its total project capital cost forecast to $10.4 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 $150 million and is based on projected in-service dates at the end of the first quarter 2023 and the fourth quarter 2023 for
Units 3 and 4, respectively. Since 2018, established construction contingency and additional costs totaling $2.2 billion have been assigned
to the base capital cost forecast. Although Georgia Power believes these incremental costs are reasonable and necessary to complete the
project and the Georgia PSC’s order in the seventeenth VCM proceeding specifically states that the construction of Plant Vogtle Units 3
and 4 is not subject to a cost cap, Georgia Power will 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 has not sought rate
recovery for the construction contingency costs. After considering the significant level of uncertainty that exists regarding the future
recoverability of these costs since the ultimate outcome of these matters is subject to the outcome of future assessments by management,
as well as Georgia PSC decisions in these future regulatory proceedings, Georgia Power recorded total pre-tax charges to income of $1.1
billion ($0.8 billion after tax) in the second quarter 2018; $149 million ($111 million after tax) and $176 million ($131 million after tax) in
the second quarter and the fourth quarter 2020, respectively; and $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.
Georgia Power and the other Vogtle Owners do not agree on either the starting dollar amount for the determination of cost increases
subject to the cost-sharing and tender provisions of the Global Amendments (as defined in Note 2 to the financial statements under
“Georgia Power – Nuclear Construction – Joint Owner Contracts”) or the extent to which COVID-19-related costs impact the calculation.
Based on the definition in the Global Amendments, Georgia Power believes the starting dollar amount is $18.38 billion and the current
project capital cost forecast has triggered the cost-sharing provisions. The other Vogtle Owners have asserted that the project cost
increases have reached the cost-sharing thresholds and have triggered the tender provisions under the Global Amendments. Georgia
Power recorded an additional pre-tax charge to income in the fourth quarter 2021 of approximately $440 million ($328 million after tax)
associated with these cost-sharing and tender provisions, which is included in the total project capital cost forecast. Georgia Power may
be required to record further pre-tax charges to income of up to approximately $460 million associated with these provisions based on the
current project capital cost forecast. The incremental charges associated with these provisions will not be recovered from retail customers.
On October 29, 2021, Georgia Power and the other Vogtle Owners entered into an agreement to clarify the process for the tender
provisions of the Global Amendments to provide for a decision between 120 and 180 days after the tender option is triggered, which
the other Vogtle Owners assert occurred on February 14, 2022. See Note 2 to the financial statements under “Georgia Power – Nuclear
Construction – Joint Owner Contracts” for additional information on the Global Amendments.
As part of its ongoing processes, Southern Nuclear continues to evaluate cost and schedule forecasts on a regular basis to incorporate
current information available, particularly in the areas of engineering support, commodity installation, system turnovers and related
test results, and workforce statistics. Georgia Power estimates the productivity impacts of the COVID-19 pandemic have consumed
approximately three to four months of schedule margin previously embedded in the site work plan for Unit 3 and Unit 4.
As Unit 3 completes system turnover from construction and moves to testing and transition to operations, ongoing and potential
future challenges include completion of construction remediation work, completion of work packages, including inspection records, and
other documentation necessary to submit the remaining ITAACs and begin fuel load, and final component and pre-operational tests.
As Unit 4 progresses through construction and continues to transition into testing, ongoing and potential future challenges include
the pace and quality of electrical installation, availability of craft and supervisory resources, including the temporary diversion of
such resources to support Unit 3 construction efforts, and the pace of work package closures and system turnovers. As construction,
including subcontract work, continues on both Units 3 and 4, ongoing or future challenges include management of contractors and
vendors; subcontractor performance; supervision of craft labor and related productivity, particularly in the installation of electrical,
mechanical, and instrumentation and controls commodities, ability to attract and retain craft labor, and/or related cost escalation; and
procurement and related installation. New challenges may arise, particularly as Units 3 and 4 move into initial testing and start-up,
which may result in required engineering changes or remediation related to plant systems, structures, or components (some of which
are based on new technology that only within the last few years began initial operation in the global nuclear industry at this scale).
The ongoing and potential future challenges described above may change the projected schedule and estimated cost. In addition,
the continuing effects of the COVID-19 pandemic could further disrupt or delay construction and testing activities at Plant Vogtle
Units 3 and 4.
There have been technical and procedural challenges to the construction and licensing of Plant Vogtle Units 3 and 4 at the federal and
state level and additional challenges may arise. Processes are in place that are designed to ensure compliance with the requirements
specified in the Westinghouse Design Control Document and the combined construction and operating licenses, including inspections
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
by Southern Nuclear and the NRC that occur throughout construction. Findings resulting from such inspections could require additional
remediation and/or further NRC oversight. In addition, certain license amendment requests have been filed and approved or are pending
before the NRC. Various design and other licensing-based compliance matters, including the timely submittal by Southern Nuclear of the
ITAAC documentation for each unit and the related reviews and approvals by the NRC necessary to support NRC authorization to load fuel,
have arisen or may arise, which may result in additional license amendments or require other resolution. If any license amendment requests
or other licensing-based compliance issues, including inspections and ITAACs, are not resolved in a timely manner, there may be delays in
the project schedule that could result in increased costs.
The ultimate outcome of these matters cannot be determined at this time. However, any extension of the in-service date beyond the first
quarter 2023 for Unit 3 or the fourth quarter 2023 for Unit 4, including the current level of cost sharing described in Note 2, is estimated
to result in additional base capital costs for Georgia Power of up to $60 million per month for Unit 3 and $40 million per month for
Unit 4, as well as the related AFUDC and any additional related construction, support resources, or testing costs. While Georgia Power is
not precluded from seeking retail recovery of any future capital cost forecast increase other than the amounts related to the cost-sharing
and tender provisions of the joint ownership agreements described above, management will ultimately determine whether or not to seek
recovery. Any further changes to the capital cost forecast that are not expected to be recoverable through regulated rates will be required
to be charged to income and such charges could be material.
Given the significant complexity involved in estimating the future costs to complete construction and start-up of Plant Vogtle Units 3 and
4 and the significant management judgment necessary to assess the related uncertainties surrounding future rate recovery of any projected
cost increases, 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, 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.
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. The apportionments and methodologies which are ultimately finalized in a manner inconsistent with expectations
could have a material effect on the financial statements of the applicable Registrants.
Given the significant judgment involved in estimating tax credit and/or state NOL carryforwards and multi-state apportionments for all
subsidiaries, the applicable Registrants consider deferred income tax liabilities and assets to be critical accounting estimates.
Asset Retirement Obligations (Southern Company, Alabama Power, Georgia Power, Mississippi Power, and
Southern Company Gas)
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.
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
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 and 2). 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. See Note 6 to the financial statements for additional
information, including increases to AROs related to ash ponds recorded during 2021 by certain Registrants.
Given the significant judgment involved in estimating AROs, the applicable Registrants consider the liabilities for AROs to be critical
accounting estimates.
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.
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
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 2022
Increase/(Decrease) in
Projected Obligation
for Pension Plan at
December 31, 2021
(in millions)
Projected Obligation for
Other Postretirement
Benefit Plans at
December 31, 2021
$44/$(43)
$12/$(12)
$12/$(12)
$2/$(2)
$–/$–
$26/$(24)
$8/$(7)
$7/$(7)
$1/$(1)
$–/$–
$41/$(41)
$10/$(10)
$13/$(13)
$2/$(2)
$3/$(3)
$610/$(575)
$149/$(140)
$180/$(170)
$27/$(26)
$40/$(38)
$131/$(127)
$37/$(36)
$37/$(36)
$6/$(6)
$2/$(2)
N/A
N/A
N/A
N/A
N/A
$53/$(51)
$14/$(13)
$18/$(17)
$2/$(2)
$6/$(6)
$–/$–
$–/$–
$–/$–
$–/$–
$–/$–
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.
Asset Impairment (Southern Company, Southern Power, and Southern Company Gas)
Goodwill (Southern Company and Southern Company Gas)
The acquisition method of accounting 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 tested for impairment at the reporting unit level on an annual basis in the
fourth quarter of the year as well as on an interim basis as events and changes in circumstances occur, including, but not limited to, a significant
change in operating performance, the business climate, legal or regulatory factors, or a planned sale or disposition of a significant portion of
the business. A reporting unit 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.
As part of the impairment tests, the applicable Registrant may perform an initial qualitative assessment to determine whether it is
more likely than not that the fair value of each reporting unit is less than its carrying amount before applying the quantitative goodwill
impairment test. If the applicable Registrant elects to perform the qualitative assessment, it evaluates relevant events and circumstances,
including but not limited to, macroeconomic conditions, industry and market conditions, cost factors, financial performance, entity specific
events, and events specific to each reporting unit. If the applicable Registrant determines that it is more likely than not that the fair value
of a reporting unit is less than its carrying amount, or it elects not to perform a qualitative assessment, it compares the fair value of the
reporting unit to its carrying value to determine if the fair value is greater than its carrying value.
Goodwill for Southern Company and Southern Company Gas was $5.3 billion and $5.0 billion, respectively, at December 31, 2021. For
its 2021 annual impairment test, Southern Company Gas performed the quantitative assessment and confirmed that the fair value of
all of its reporting units with goodwill exceeded their carrying value. For its 2020 and 2019 annual impairment tests, Southern Company
Gas 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 annual impairment tests
for PowerSecure, Southern Company performed the quantitative assessment, which resulted in the fair value of goodwill at PowerSecure
exceeding its carrying value in all years presented. However, Southern Company recorded goodwill impairment charges totaling $34 million
in 2019 as a result of its decision to sell certain PowerSecure business units. See Note 15 to the financial statements under “Southern
Company” for additional information. The COVID-19 pandemic and the related impacts on the worldwide economy have disrupted supply
chains, reduced labor availability and productivity, and reduced economic activity in the United States. These effects have had a variety
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
of adverse impacts on Southern Company and its subsidiaries, including PowerSecure. If these factors continue to negatively affect the
operating results of PowerSecure and its businesses, a portion of the associated goodwill of $263 million may become impaired. The
ultimate outcome of this matter cannot be determined at this time.
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 and Liabilities” for additional information regarding the
applicable Registrants’ goodwill.
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 indicator exists, the asset is tested for recoverability by comparing the asset
carrying value 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 value of the asset, the fair value of the asset is determined and
a loss is recorded equal to the difference between the carrying value 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 value 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. Impairments of long-lived assets of the traditional electric utilities
and natural gas distribution utilities are generally related to specific regulatory disallowances.
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 and storage facility assets, whether in service or
under construction.
For Southern Power, examples of impairment indicators could include 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, 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 and 2020, Southern Company recorded impairment charges totaling $7 million ($6 million after tax) and $206 million
($105 million after tax), respectively, related to its leveraged lease investments. During 2021, Southern Company Gas recorded total pre-tax
charges of $84 million ($67 million after tax) related to its equity method investment in the PennEast Pipeline project. During 2019,
Southern Company Gas recorded pre-tax impairment charges of $91 million ($69 million after-tax) related to a natural gas storage facility
and approximately $24 million ($17 million after tax) related to the sale of Pivotal LNG. 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.
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Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Recently Issued Accounting Standards
In March 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 amendments in ASU 2020-04 are
elective and apply to all entities that have contracts, hedging relationships, and other transactions that reference LIBOR or another reference
rate expected to be discontinued. The new guidance (i) simplifies accounting analyses under current GAAP for contract modifications; (ii)
simplifies the assessment of hedge effectiveness and allows hedging relationships affected by reference rate reform to continue; and (iii)
allows 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 may elect to apply the amendments prospectively from March 12, 2020 through December 31, 2022 by accounting topic.
The Registrants have elected to apply the amendments to modifications of debt arrangements that meet the scope of ASU 2020-04.
The Registrants currently reference LIBOR for certain debt and hedging arrangements. In addition, certain provisions in PPAs at Southern
Power include references to LIBOR. Contract language has been, or is expected to be, incorporated into each of these agreements to
address the transition to an alternative rate for agreements that will be in place at the transition date. While no material impacts are
expected from modifications to the arrangements and effective hedging relationships are expected to continue, the Registrants will
continue to evaluate the provisions of ASU 2020–04 and the impacts of transitioning to an alternative rate, and the ultimate outcome
of the transition cannot be determined at this time. See FINANCIAL CONDITION AND LIQUIDITY – “Overview” and “Financing Activities”
herein and Note 14 to the financial statements under “Interest Rate Derivatives” for additional information.
FINANCIAL CONDITION AND LIQUIDITY
Overview
The financial condition of each Registrant remained stable at December 31, 2021. 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 2021, Southern Power utilized tax credits, which
provided $288 million in operating cash flows. For the three-year period from 2022 through 2024, each Registrant’s projected stock dividends,
capital expenditures, and debt maturities, as well as distributions to noncontrolling interests for Southern Power, are expected to exceed its
operating cash flows. 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 plans to 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.
To facilitate an orderly transition from LIBOR to alternative benchmark rate(s), the Registrants have established an initiative to assess and
mitigate risks associated with the discontinuation of LIBOR. As part of this initiative, several alternative benchmark rates have been, and
continue to be, evaluated and implemented. Substantially all of the Registrants’ credit facilities allow for LIBOR to be phased out and replaced
with the Secured Overnight Financing Rate and interest rate derivatives address the LIBOR transition through the adoption of the ISDA 2020
IBOR Fallbacks Protocol and subsequent amendments. None of the Registrants expects the transition from LIBOR to have a material impact.
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, 2021 as compared to December 31, 2020. No contributions to the qualified
pension plan were made during 2021 and no mandatory contributions to the qualified pension plans are anticipated during 2022. See Notes 6
and 11 to the financial statements under “Nuclear Decommissioning” and “Pension Plans,” respectively, for additional information.
At the end of 2021, the market price of Southern Company’s common stock was $68.58 per share (based on the closing price as reported
on the NYSE) and the book value was $26.30 per share, representing a market-to-book value ratio of 261%, compared to $61.43, $26.48,
and 232%, respectively, at the end of 2020.
57
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Cash Requirements
Capital Expenditures
Total estimated capital expenditures, including LTSA and nuclear fuel commitments, for the Registrants through 2026 based on their current
construction programs are as follows:
Southern Company(a)(b)(c)
Alabama Power(a)
Georgia Power(b)
Mississippi Power
Southern Power(c)
Southern Company Gas
2022
2023
2024
(in billions)
2025
2026
$8.7
1.9
4.4
0.3
0.1
1.7
$8.6
1.8
4.5
0.3
0.2
1.7
$7.5
1.7
3.5
0.2
0.1
1.8
$7.2
1.7
3.5
0.2
0.1
1.7
$7.1
1.7
3.4
0.2
0.1
1.7
(a) Includes expenditures of approximately $0.3 billion and $0.1 billion for the construction of Plant Barry Unit 8 in 2022 and 2023, respectively. See Note 2 to
the financial statements under “Alabama Power” for additional information.
(b) Includes expenditures of approximately $1.3 billion and $0.9 billion for the construction of Plant Vogtle Units 3 and 4 in 2022 and 2023, respectively.
(c) Excludes approximately $0.3 billion in 2022, $0.5 billion in 2023, and $0.8 billion per year for 2024 through 2026 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.
These capital expenditures include estimates to comply with environmental laws and regulations, but do not include any potential
compliance costs associated with any future regulation of CO2 emissions from fossil fuel-fired electric generating units. See FUTURE
EARNINGS POTENTIAL – “Environmental Matters” herein for additional information. At December 31, 2021, significant purchase
commitments were outstanding in connection with the Registrants’ construction programs.
The traditional electric operating companies also anticipate 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 and Mississippi Power are based on closure-in-place for all ash ponds. The cost estimates for Georgia Power
are based on a combination of closure-in-place for some ash ponds and closure by removal for others. These anticipated 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 2026 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
2022
2023
2024
2025
2026
$687
320
317
16
(in millions)
$767
346
368
23
$688
330
307
20
$907
364
489
30
$888
299
555
16
The construction programs are subject to periodic review and revision, and actual construction costs may vary from these estimates because
of numerous factors. These factors include: changes in business conditions; changes in load projections; changes in environmental laws and
regulations; the outcome of any legal challenges to environmental rules; changes in electric generating plants, including unit retirements
and replacements and adding or changing fuel sources at existing electric generating units, to meet regulatory requirements; changes in
FERC rules and regulations; state regulatory agency approvals; changes in the expected environmental compliance program; changes in
legislation and/or regulation; the cost, availability, and efficiency of construction labor, equipment, and materials; project scope and design
changes; abnormal weather; delays in construction due to judicial or regulatory action; storm impacts; and the cost of capital. The continued
impacts of the COVID-19 pandemic could also impair the ability to develop, construct, and operate facilities. 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.
The construction program of Georgia Power includes Plant Vogtle Units 3 and 4, which includes components based on new technology that
only within the last few years began initial operation in the global nuclear industry at this scale and which may be subject to additional
revised cost estimates during construction. See Note 2 to the financial statements under “Georgia Power – Nuclear Construction” for
information regarding Plant Vogtle Units 3 and 4 and additional factors that may impact construction expenditures.
See FUTURE EARNINGS POTENTIAL – “Construction Programs” herein for additional information.
58
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
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, 2021, 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, 2021 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, 2021. As discussed under “Capital Expenditures” herein,
estimated expenditures for nuclear fuel are included in the applicable Registrants’ construction programs for the years 2022 through
2026. Nuclear fuel commitments at December 31, 2021 that extend beyond 2026 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
2022
2023
2024
2025
2026
Thereafter
(in millions)
$3,740
1,170
1,405
539
626
$1,983
581
795
235
372
$1,302
446
440
168
248
$969
358
348
109
154
$753
203
329
98
123
$5,803
1,182
4,118
491
12
(*) Excludes capacity payments related to Plant Vogtle Units 1 and 2, which are discussed in Note 3 to the financial statements under “Commitments.”
Georgia Power’s 2022 IRP filing included a request for six PPAs, which are expected to be accounted for as leases, that are contingent
upon approval by the Georgia PSC. Five of the six PPAs are with Southern Power and are also contingent upon approval by the FERC. The
expected capacity payments associated with the PPAs total $6 million in 2024, $79 million in 2025, $86 million in 2026, and $908 million
thereafter, of which $5 million in 2024, $68 million in 2025, $75 million in 2026, and $748 million thereafter relate to the affiliate PPAs
with Southern Power. See Note 2 to the financial statements under “Georgia Power – Integrated Resource Plan” 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 2022 through 2026. Total estimated payments for LTSA commitments at December 31,
2021 that extend beyond 2026 are provided in the following table and include price escalation based on inflation indices:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
LTSA commitments (after 2026)
$1,918
$203
$347
$137
$1,231
In addition, Southern Power has certain other operations and maintenance agreements. Total estimated costs for these commitments at
December 31, 2021 are provided in the table below.
Southern Power’s operations and maintenance agreements
$77
$65
$62
$47
$36
$303
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.
2022
2023
2024
2025
(in millions)
2026
Thereafter
59
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Sources of Capital
Southern Company intends to meet its future capital needs through operating cash flows, borrowings from financial institutions, and debt
and equity issuances. Equity capital can be provided from any combination of Southern Company’s stock plans, private placements, or
public offerings. Southern Company does not expect to issue any equity in the capital markets through 2026 but may issue equity through
its stock plans during this time. See Note 8 to the financial statements under “Equity Units” for information on stock purchase contracts
associated with Southern Company’s equity units.
The Subsidiary Registrants plan to obtain the funds to meet their future capital needs from sources similar to those they used in the
past, which were primarily from operating cash flows, external securities issuances, borrowings from financial institutions, and equity
contributions from Southern Company. In addition, Southern Power plans to utilize tax equity partnership contributions (as discussed
further herein).
The amount, type, and timing of any financings in 2022, as well as in subsequent years, will be contingent on investment opportunities
and the Registrants’ capital requirements and will depend upon prevailing market conditions, regulatory approvals (for certain of the
Subsidiary Registrants), and other factors. See “Cash Requirements” 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 2021, Southern Power obtained tax equity funding for the Deuel Harvest
wind facility, the Garland and Tranquillity battery energy storage facilities, and existing tax equity partnerships totaling $299 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.
By regulation, Nicor Gas is restricted, to the extent of its retained earnings balance, in the amount it can dividend or loan to affiliates
and is not permitted to make money pool loans to affiliates. At December 31, 2021, the amount of subsidiary retained earnings
restricted to dividend totaled $1.3 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.
60
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
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, 2021. The following table shows the amount by which
current liabilities exceeded current assets at December 31, 2021 for the applicable Registrants:
At December 31, 2021
Southern
Company
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
Current liabilities in excess of current assets
$1,956
$1,544
$57
$748
$471
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, 2021, the Registrants’ unused committed credit arrangements with banks were as follows:
At December 31, 2021
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
$1,250
$1,726
$275
$568
$1,747
$30
$7,594
(a) At December 31, 2021, Southern Power also had two continuing letters of credit facilities for standby letters of credit, of which $12 million was unused.
Southern Power’s subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.
(b) Includes $1.047 billion and $700 million at Southern Company Gas Capital and Nicor Gas, respectively.
Subject to applicable market conditions, the Registrants, Nicor Gas, and SEGCO expect to renew or replace their bank credit arrangements
as needed, prior to expiration. In connection therewith, the Registrants, Nicor Gas, and SEGCO may extend the maturity dates and/or
increase or decrease the lending commitments thereunder. A portion of the unused credit with banks is allocated to provide liquidity
support to the revenue bonds of the traditional electric operating companies and the commercial paper programs of the Registrants, Nicor
Gas, and SEGCO. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity
support at December 31, 2021 was approximately $1.5 billion (comprised of approximately $789 million at Alabama Power, $672 million
at Georgia Power, and $34 million at Mississippi Power). In addition, at December 31, 2021, Georgia Power had approximately $157 million
of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months. See Note 8 to the financial
statements under “Bank Credit Arrangements” for additional information.
61
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Short-term Borrowings
The Registrants, Nicor Gas, and SEGCO make short-term borrowings primarily through commercial paper programs that have the liquidity
support of the committed bank credit arrangements described above. Southern Power’s subsidiaries are not issuers or obligors under its
commercial paper program. Commercial paper and short-term bank term loans are included in notes payable in the balance sheets. Details
of the Registrants’ short-term borrowings were as follows:
Short-term Debt at the End of the Period
Amount
Outstanding
December 31,
2021
2020
(in millions)
Weighted Average
Interest Rate
December 31,
2019
2021
2020
2019
$ 1,440
—
—
211
$ 379
830
$ 1,209
$609
60
25
175
$220
104
$324
$2,055
365
—
549
$ 372
278
$ 650
0.4%
—
—
0.3
0.3%
0.4%
0.4%
0.3%
0.3
0.4
0.3
0.3%
0.2
0.2%
2.1%
2.2
—
2.2
2.1%
1.8
2.0%
Short-term Debt During the Period(*)
Weighted Average
Interest Rate
Maximum Amount
Outstanding
2019
2021
2020
2019
2021
2020
(in millions)
$2,113
155
478
40
550
2019
$2,914
190
935
—
578
$ 641
278
$ 490
278
Southern Company
Georgia Power
Mississippi Power
Southern Power
Southern Company Gas:
Southern Company Gas Capital
Nicor Gas
Southern Company Gas Total
Average Amount
Outstanding
2021
2020
(in millions)
Southern Company
Alabama Power
Georgia Power
Mississippi Power
Southern Power
Southern Company Gas:
Southern Company Gas Capital
Nicor Gas
Southern Company Gas Total
$1,141
27
95
15
133
$ 206
420
$ 626
$1,017
20
264
9
64
$ 316
49
$ 365
$1,240
17
371
—
76
$ 302
91
$ 393
0.3%
0.1
0.2
0.2
0.2
0.2%
0.4
0.4%
1.6%
1.1
1.7
1.6
1.5
1.4%
1.4
1.4%
2.6% $1,809
200
2.6
407
2.7
81
—
520
2.7
2.6% $ 485
2.3
897
2.5%
(*) Average and maximum amounts are based upon daily balances during the 12-month periods ended December 31, 2021, 2020, and 2019.
62
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Analysis of Cash Flows
Net cash flows provided from (used for) operating, investing, and financing activities in 2021 and 2020 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
2021
Operating activities
Investing activities
Financing activities
2020
Operating activities
Investing activities
Financing activities
(in millions)
$ 6,169
(7,353)
1,945
$ 2,053
(1,961)
438
$ 2,747
(3,590)
867
$ 246
(257)
33
$
951
(803)
(195)
$ 6,696
(7,030)
(576)
$ 1,742
(2,122)
16
$ 2,784
(3,503)
676
$ 298
(323)
(222)
$
901
374
(1,372)
$
663
(1,379)
745
$ 1,207
(1,417)
180
Fluctuations in cash flows from financing activities vary from year to year based on capital needs and the maturity or redemption of
securities.
Southern Company
Net cash provided from operating activities decreased $0.5 billion in 2021 as compared to 2020 largely due to decreased fuel cost recovery
at the traditional electric operating companies and under recovered natural gas costs at the natural gas distribution utilities, partially offset
by customer bill credits issued in 2020 at Georgia Power and the timing of customer receivable collections.
The net cash used for investing activities in 2021 and 2020 was primarily related to the Subsidiary Registrants’ construction programs.
The net cash provided from financing activities in 2021 was primarily related to net issuances of long-term and short-term debt, partially
offset by common stock dividend payments. The net cash used for financing activities in 2020 was primarily related to common stock
dividend payments and net repayments of short-term bank debt and commercial paper, partially offset by net issuances of long-term debt
and issuances of common stock.
Significant Balance Sheet Changes
Southern Company
Significant balance sheet changes in 2021 for Southern Company included:
O an increase of $3.7 billion in long-term debt (including securities due within one year) related to new issuances;
O an increase of $3.5 billion in total property, plant, and equipment primarily related to the Subsidiary Registrants’ construction programs
(net of pre-tax charges totaling $1.7 billion recorded during 2021 at Georgia Power for estimated probable losses associated with the
construction of Plant Vogtle Units 3 and 4);
O decreases of $1.8 billion and $0.7 billion in other regulatory assets and employee benefit obligations, respectively, and an increase of
$1.7 billion in prepaid pension costs primarily due to actuarial gains related to increases in the assumed discount rates and actual asset
returns associated with retirement benefit plans;
O increases of $1.0 billion and $0.5 billion in AROs and regulatory assets associated with AROs, respectively, primarily related to cost
estimate updates at the traditional electric operating companies for ash pond facilities;
O an increase of $0.8 billion in notes payable due to an increase in commercial paper borrowings and short-term bank debt;
O an increase of $0.7 billion in accumulated deferred income taxes primarily related to the utilization of tax credits in 2021, an increase in
under recovered fuel and natural gas costs, and an increase in property-related timing differences; and
O an increase of $0.7 billion in cash and cash equivalents, as discussed further under “Analysis of Cash Flows – Southern Company” herein.
See “Financing Activities” herein and Notes 2, 5, 6, 8, 10, and 11 to the financial statements for additional information.
63
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Financing Activities
The following table outlines the Registrants’ long-term debt financing activities for the year ended December 31, 2021:
Company
Southern Company parent
Alabama Power
Georgia Power
Mississippi Power
Southern Power
Southern Company Gas
Other
Elimination(b)
Southern Company
Issuances/Reofferings
Maturities, Redemptions,
and Repurchases
Senior
Notes
Revenue
Bonds
Other Long-
Term Debt
Senior
Notes
Revenue
Bonds
Other Long-
Term Debt(a)
$1,600
1,300
750
525
400
450
—
—
$5,025
$ —
—
122
—
—
—
—
—
$122
(in millions)
$2,476
—
440
—
—
200
—
—
$3,116
$1,500
200
325
—
300
300
—
—
$2,625
$ —
65
69
320
—
—
—
—
$454
$ 800
207
105
100
—
30
14
(7)
$1,249
(a) Includes reductions in finance lease obligations resulting from cash payments under finance leases and, for Georgia Power, principal amortization payments
for FFB borrowings.
(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 2021, Southern Company issued approximately 3.5 million shares of common stock primarily through employee equity
compensation plans and received proceeds of approximately $73 million.
In January 2021, Southern Company borrowed $25 million pursuant to a short-term uncommitted bank credit arrangement, which it repaid
in March 2021.
In February 2021, Southern Company issued $600 million aggregate principal amount of Series 2021A 0.60% Senior Notes due February 26,
2024 and $400 million aggregate principal amount of Series 2021B 1.75% Senior Notes due March 15, 2028.
In May 2021, Southern Company issued $1.0 billion aggregate principal amount of Series 2021A 3.75% Fixed-to-Fixed Reset Rate Junior
Subordinated Notes due September 15, 2051.
Also in May 2021, Southern Company redeemed all of its $1.5 billion aggregate principal amount of 2.35% Senior Notes due July 1, 2021.
In September 2021, Southern Company issued €1.25 billion (approximately $1.476 billion) aggregate principal amount of Series 2021B
1.875% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due September 15, 2081. Southern Company’s obligations under these notes
were effectively converted to fixed-rate U.S. dollars at issuance for the first six years through cross-currency swaps, mitigating foreign
currency exchange risk associated with the interest and principal payments during this period. See Note 14 to the financial statements
under “Foreign Currency Derivatives” for additional information.
In October 2021, Southern Company redeemed all $800 million aggregate principal amount of its Series 2016A 5.25% Junior Subordinated
Notes due October 1, 2076.
In November 2021, Southern Company issued $600 million aggregate principal amount of Series 2021C Floating Rate Senior Notes due
May 10, 2023.
64
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Alabama Power
In March 2021, Alabama Power extended the maturity dates from March 2021 to March 2026 on its three bank term loan agreements
with an aggregate principal amount of $45 million, currently bearing interest based on three-month LIBOR.
In June 2021, Alabama Power repaid at maturity $200 million aggregate principal amount of its Series 2011B 3.950% Senior Notes.
Also in June 2021, Alabama Power issued $600 million aggregate principal amount of Series 2021A 3.125% Senior Notes due July 15, 2051.
In July 2021, Alabama Power redeemed all of its approximately $206 million aggregate principal amount of Series E Junior Subordinated
Notes due October 1, 2042. The Series E Junior Subordinated Notes were held by an affiliated trust, Alabama Power Capital Trust V,
which applied the redemption proceeds to the simultaneous redemption of (i) its Flexible Trust Preferred Securities totaling approximately
$200 million, which were guaranteed by Alabama Power, and (ii) shares of its common securities totaling approximately $6 million that
were held by Alabama Power.
In November 2021, Alabama Power repaid at maturity $65 million aggregate principal amount of The Industrial Development Board of the
Town of Columbia (Alabama) Tax Exempt Variable Rate Demand Revenue Bonds (Alabama Power Company Project), Series 1997.
Also in November 2021, Alabama Power issued $700 million aggregate principal amount of Series 2021B 3.00% Senior Notes due
March 15, 2052.
Subsequent to December 31, 2021, Alabama Power received a capital contribution totaling $625 million from Southern Company and
announced the redemption in February 2022 of all $550 million aggregate principal amount of its Series 2017A 2.45% Senior Notes due
March 30, 2022.
Georgia Power
In February 2021, Georgia Power issued $750 million aggregate principal amount of Series 2021A 3.25% Senior Notes due March 15,
2051. An amount equal to the net proceeds of the senior notes is being allocated to finance or refinance, in whole or in part, one or more
renewable energy projects and/or expenditures and programs related to enabling opportunities for diverse and small businesses/suppliers.
In March 2021, Georgia Power redeemed all $325 million aggregate principal amount of its Series 2016B 2.40% Senior Notes due April 1, 2021.
Also in March 2021, Georgia Power extended the maturity date of its $125 million term loan from June 2021 to June 2022.
In June 2021, Georgia Power purchased and held approximately $69 million aggregate principal amount of Development Authority of
Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), First Series 2008. In August 2021,
Georgia Power reoffered these bonds to the public.
In June 2021 and December 2021, Georgia Power made the final borrowings under the FFB Credit Facilities in aggregate principal amounts
of $371 million and $69 million, respectively, at an interest rate of 2.434% and 2.178%, respectively, through the final maturity date of
February 20, 2044. No further borrowings are permitted under the FFB Credit Facilities. The proceeds were used to reimburse Georgia
Power for Eligible Project Costs relating to the construction of Plant Vogtle Units 3 and 4. During 2021, Georgia Power made principal
amortization payments of $96 million under the FFB Credit Facilities. See Note 8 to the financial statements under “Long-term Debt –
DOE Loan Guarantee Borrowings” for additional information.
In August 2021, Georgia Power reoffered to the public $53 million aggregate principal amount of Development Authority of Floyd County
(Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Hammond Project), First Series 2010, which it had previously
purchased and held.
Subsequent to December 31, 2021, Georgia Power redeemed all $400 million aggregate principal amount of its Series 2012B 2.85% Senior
Notes due May 15, 2022.
Mississippi Power
In June 2021, Mississippi Power issued $200 million aggregate principal amount of Series 2021A Floating Rate Senior Notes due June 28,
2024 and $325 million aggregate principal amount of Series 2021B 3.10% Senior Notes due July 30, 2051. An amount equal to the net
proceeds of the Series 2021B Senior Notes is being allocated to finance or refinance, in whole or in part, one or more renewable energy
projects and/or expenditures and programs related to enabling opportunities for diverse and small businesses/suppliers.
In July 2021, Mississippi Power redeemed all $270 million aggregate principal amount of Mississippi Business Finance Corporation Taxable
Revenue Bonds, 7.13% Series 1999A due October 20, 2021 at par plus accrued interest and a make-whole premium.
65
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
Also in July 2021, Mississippi Power repaid its $60 million and $15 million floating rate bank term loans, with maturity dates in December
2021 and January 2022, respectively.
In October 2021, Mississippi Power repaid $25 million previously borrowed under its $125 million revolving credit arrangement that
matures in March 2023.
In December 2021, Mississippi Power redeemed all $50 million aggregate principal amount of Mississippi Business Finance Corporation
Revenue Bonds, First Series 2010 due December 1, 2040.
Subsequent to December 31, 2021, Mississippi Power received a capital contribution totaling $50 million from Southern Company.
Southern Power
In January 2021, Southern Power issued $400 million aggregate principal amount of Series 2021A 0.90% Senior Notes due January 15,
2026. An amount equal to the net proceeds of the senior notes was allocated to finance or refinance, in whole or in part, one or more
renewable energy projects.
In November 2021, Southern Power redeemed all $300 million aggregate principal amount of its Series 2016E 2.500% Senior Notes due
December 15, 2021.
Southern Company Gas
In February 2021, Atlanta Gas Light repaid at maturity $30 million aggregate principal amount of 9.1% medium-term notes.
In March 2021, Nicor Gas entered into three short-term floating rate bank loans in an aggregate principal amount of $300 million, each
bearing interest based on one-month LIBOR.
In June 2021, Southern Company Gas Capital redeemed all $300 million aggregate principal amount of its 3.50% Senior Notes due
September 15, 2021.
In August 2021, Nicor Gas issued in a private placement $50 million aggregate principal amount of 1.42% Series First Mortgage Bonds due
August 31, 2026 and $50 million aggregate principal amount of 2.19% Series First Mortgage Bonds due August 31, 2033. In October 2021,
Nicor Gas issued in a private placement $100 million aggregate principal amount of 1.77% Series First Mortgage Bonds due October 28,
2028. Nicor Gas also entered into an agreement to issue in a private placement additional first mortgage bonds with aggregate principal
amounts of $100 million and $75 million expected to be issued in August 2022 and October 2022, respectively.
In September 2021, Southern Company Gas Capital, as borrower, and Southern Company Gas, as guarantor, issued $450 million aggregate
principal amount of Series 2021A 3.15% Senior Notes due September 30, 2051.
Credit Rating Risk
At December 31, 2021, the Registrants did not have any credit arrangements that would require material changes in payment schedules or
terminations as a result of a credit rating downgrade.
There are certain contracts that could require collateral, but not accelerated payment, in the event of a credit rating change of certain
Registrants to BBB and/or Baa2 or below. These contracts are primarily for physical electricity and natural gas purchases and sales, fuel
purchases, fuel transportation and storage, energy price risk management, transmission, interest rate management, and, for Georgia Power,
construction of new generation at Plant Vogtle Units 3 and 4.
The maximum potential collateral requirements under these contracts at December 31, 2021 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)
$
41
419
1,934
$
1
2
407
$ —
61
939
$ —
1
307
$
40
357
1,186
$—
—
9
(*) 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 $105 million of cash collateral posted related to PPA requirements at December 31, 2021.
66
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
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, 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 October 27, 2021, S&P downgraded the Southern Company issuer credit rating to BBB+ from A-. Due to S&P’s consolidated rating
methodology, the downgrade of Southern Company’s issuer credit rating resulted in the downgrade of the senior unsecured long-term debt
rating of Alabama Power and the long-term issuer rating of Nicor Gas to A- from A, the senior unsecured long-term debt ratings of Atlanta
Gas Light, Georgia Power, Mississippi Power, and Southern Company Gas Capital to BBB+ from A-, and the senior unsecured long-term debt
ratings of Southern Company and Southern Power to BBB from BBB+. S&P revised its credit rating outlook for Southern Company and its
subsidiaries to stable from negative.
Market Price Risk
As a result of the sale of Sequent on July 1, 2021, Southern Company Gas’ market risk exposure decreased significantly. The other
Registrants had no material change in market risk exposure for the year ended December 31, 2021 when compared to the year ended
December 31, 2020. 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. See Note 15 to the financial statements under “Southern
Company Gas” for information regarding the sale of Sequent.
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 (primarily Sequent until its sale on July 1, 2021) 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.
67
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following table provides information related to variable interest rate exposure on long-term debt (including amounts due within one
year) at December 31, 2021 for the applicable Registrants:
At December 31, 2021
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
$4,464
$ 834
$ 797
$ 234
$ 500
(in millions, except percentages)
rate exposure
0.84%
0.21%
0.21%
0.32%
0.49%
Impact on annualized interest expense of 100 basis point
change in interest rates
$
45
$
8
$
8
$
2
$
5
(*) Includes $2.0 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, 2021 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, 2021 and 2020 are provided in the table below. At December 31, 2021 and 2020, 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, 2019, assets (liabilities), net
Contracts realized or settled
Current period changes(b)
Contracts outstanding at December 31, 2020, assets (liabilities), net
Contracts realized or settled
Current period changes(b)
Sale of Sequent
Contracts outstanding at December 31, 2021, assets (liabilities), net
Southern
Company(a)
Southern
Company Gas(a)
(in millions)
$ (21)
(14)
142
$ 107
(252)
243
76
$ 174
$ 72
(98)
127
$101
(85)
(84)
76
8
$
(a) Excludes cash collateral held on deposit in broker margin accounts of $3 million, $28 million, and $99 million at December 31, 2021, 2020, and 2019, 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, 2021 and 2020 for
Southern Company and Southern Company Gas were as follows:
At December 31, 2021:
Commodity – Natural gas swaps
Commodity – Natural gas options
Total hedge volume
At December 31, 2020:
Commodity – Natural gas swaps
Commodity – Natural gas options
Total hedge volume
68
Southern
Company
Southern
Company Gas
mmBtu Volume (in millions)
57
253
310
262
574
836
—
68
68
—
523
523
Southern Company 2021 Annual Report Management’s Discussion and Analysis of Financial Condition and Results of Operations
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 74 million mmBtu and short natural gas positions of 6 million mmBtu at December
31, 2021 and the net of long natural gas positions of 4.42 billion mmBtu and short natural gas positions of 3.90 billion mmBtu at
December 31, 2020.
For the Southern Company system, the weighted average swap contract cost per mmBtu was approximately $0.74 per mmBtu below
market prices at December 31, 2021 and was equal to market prices at December 31, 2020. 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, 2021 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)
Fair Value Measurements of Contracts at
December 31, 2021
Total
Fair Value
$ 15
159
$174
2022
$ 14
93
$107
$ 15
(7)
8
$
$ 14
(7)
7
$
Maturity
2023 – 2024
(in millions)
2025 – 2026
$ 1
65
$66
$ 1
—
$ 1
$—
1
$ 1
$—
—
$—
(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 $3 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 16 Marketers in Georgia.
For 2021, the four largest Marketers based on customer count, which includes SouthStar, accounted for 15% of Southern Company Gas’
operating revenues.
69
Southern Company 2021 Annual Report Consolidated Statements of Income
For the Years Ended December 31, 2021, 2020, and 2019
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
Gain on dispositions, net
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
Impairment of leveraged leases
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.
2021
2020
2019
(in millions)
$14,852
2,455
718
4,380
708
23,113
$13,643
1,945
672
3,434
681
20,375
$14,084
2,152
636
3,792
755
21,419
4,010
978
1,619
357
6,088
3,565
1,290
1,692
2
(186)
19,415
3,698
190
76
(1,837)
(7)
456
(1,122)
2,576
267
2,309
15
(99)
$ 2,393
2,967
799
972
327
5,413
3,518
1,234
325
—
(65)
15,490
4,885
149
153
(1,821)
(206)
336
(1,389)
3,496
393
3,103
15
(31)
$ 3,119
3,622
816
1,319
435
5,624
3,038
1,230
—
168
(2,569)
13,683
7,736
128
162
(1,736)
—
252
(1,194)
6,542
1,798
4,744
15
(10)
$ 4,739
$
2.26
2.24
$
2.95
2.93
$
4.53
4.50
1,061
1,068
1,058
1,065
1,046
1,054
70
Southern Company 2021 Annual Report Consolidated Statements of Comprehensive Income
For the Years Ended December 31, 2021, 2020, and 2019
Consolidated Net Income
Other comprehensive income (loss):
Qualifying hedges:
Changes in fair value, net of tax of $(16), $3, and $(39), respectively
Reclassification adjustment for amounts included in net income,
net of tax of $31, $(13), and $19, respectively
Pension and other postretirement benefit plans:
Benefit plan net gain (loss), net of tax of $37, $(17), and $(31), respectively
Reclassification adjustment for amounts included in net income,
net of tax of $5, $3, and $1, 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.
2021
2020
2019
(in millions)
$2,309
$3,103
$ 4,744
(49)
10
(115)
96
98
(40)
57
(55)
(64)
13
158
15
(99)
$2,551
10
(75)
15
(31)
$3,044
4
(118)
15
(10)
$ 4,621
71
Southern Company 2021 Annual Report 2021
2020
2019
(in millions)
$ 2,309
$ 3,103
$ 4,744
3,973
(49)
288
(190)
(305)
—
(456)
288
144
1,692
91
(176)
(536)
(207)
86
(81)
(130)
(266)
(170)
(8)
(54)
(155)
130
(49)
6,169
(345)
(7,240)
(1,598)
1,593
917
(442)
(124)
(188)
74
(7,353)
3,905
(241)
341
(149)
(259)
(2)
(442)
325
113
325
206
(66)
—
—
(74)
(222)
(157)
—
(161)
(27)
242
96
(236)
76
6,696
(81)
(7,441)
(877)
871
1,049
(361)
37
(211)
(16)
(7,030)
3,331
611
757
(128)
(204)
(1,136)
(328)
168
107
—
168
(2,588)
—
—
115
630
(17)
—
12
(693)
117
62
126
(73)
5,781
(50)
(7,555)
(888)
882
5,122
(393)
(169)
(234)
(107)
(3,392)
Consolidated Statements of Cash Flows
For the Years Ended December 31, 2021, 2020, and 2019
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
Pension and postretirement funding
Settlement of asset retirement obligations
Storm damage accruals
Stock based compensation expense
Estimated loss on Plant Vogtle Units 3 and 4
Impairment charges
Gain on dispositions, net
Retail fuel cost under recovery – long-term
Natural gas cost under recovery – long-term
Other, net
Changes in certain current assets and liabilities —
—Receivables
—Materials and supplies
—Natural gas cost under recovery
—Other current assets
—Accounts payable
—Accrued taxes
—Retail fuel cost over recovery
—Customer refunds
—Other current liabilities
Net cash provided from operating activities
Investing Activities:
Business acquisitions, net of cash acquired
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
72
Southern Company 2021 Annual Report Consolidated Statements of Cash Flows (continued)
For the Years Ended December 31, 2021, 2020, and 2019
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
Capital contributions from noncontrolling interests
Distributions to noncontrolling interests
Payment of common stock dividends
Other financing activities
Net cash provided from (used for) 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 $92, $81, and $74 capitalized, respectively)
Income taxes, net
Noncash transactions —
Accrued property additions at year-end
Contributions from noncontrolling interests
Contributions of wind turbine equipment
The accompanying notes are an integral part of these consolidated financial statements.
2021
2020
2019
(in millions)
530
(1,096)
640
8,262
325
73
8,047
615
74
5,220
350
844
(4,327)
(25)
501
(351)
(2,777)
(266)
1,945
761
1,068
$ 1,829
(4,458)
(840)
363
(271)
(2,685)
(325)
(576)
(910)
1,978
$ 1,068
(4,347)
(1,850)
196
(256)
(2,570)
(157)
(1,930)
459
1,519
$ 1,978
$ 1,718
93
$ 1,683
64
$ 1,651
276
866
89
82
989
12
17
932
80
26
73
Southern Company 2021 Annual Report Consolidated Balance Sheets
At December 31, 2021 and 2020
Assets
Current Assets:
Cash and cash equivalents
Receivables —
Customer accounts
Energy marketing
Unbilled 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
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 $307 and $328, respectively
Leveraged leases
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
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.
74
2021
2020
(in millions)
$ 1,798
$
1,065
1,806
—
711
523
(78)
1,543
450
362
330
151
219
266
653
231
8,965
115,592
34,079
81,513
824
8,771
91,108
5,280
2,542
1,282
445
—
653
10,202
1,701
824
1,657
258
5,466
5,577
1,776
17,259
$127,534
1,753
516
672
512
(118)
1,478
550
460
276
147
214
—
810
282
8,617
110,516
32,397
78,119
818
8,697
87,634
5,280
2,303
1,362
487
556
398
10,386
1,802
796
—
280
4,934
7,198
1,288
16,298
$122,935
Southern Company 2021 Annual Report Consolidated Balance Sheets (continued)
At December 31, 2021 and 2020
Liabilities and Stockholders’ Equity
Current Liabilities:
Securities due within one year
Notes payable
Energy marketing trade payables
Accounts payable
Customer deposits
Accrued taxes —
Accrued income taxes
Other accrued taxes
Accrued interest
Accrued compensation
Asset retirement obligations
Operating lease obligations
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
Redeemable Preferred Stock of Subsidiaries:
Cumulative preferred stock
$100 par or stated value - 4.20% to 4.92%
(Authorized - 10 million shares; Outstanding - 0.5 million shares)
$1 par value - 5.00% (Authorized - 28 million shares; Outstanding - 10 million shares)
Total redeemable preferred stock of subsidiaries (annual dividend requirement - $15 million)
Common Stockholders’ Equity:
Common stock, par value $5 per share (Authorized - 1.5 billion shares)
(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.
2021
2020
(in millions)
$
2,157
1,440
—
2,169
479
50
641
533
1,070
697
250
563
872
10,921
50,120
8,862
5,401
2,216
1,550
1,503
10,990
2,103
485
816
33,926
94,967
$
3,507
609
494
2,312
487
130
699
513
1,025
585
241
509
968
12,079
45,073
8,175
5,767
2,235
2,213
1,611
10,099
2,211
251
696
33,258
90,410
48
243
291
48
243
291
5,279
5,268
11,950
(47)
10,929
(237)
27,874
4,402
32,276
$127,534
11,834
(46)
11,311
(395)
27,972
4,262
32,234
$122,935
75
Southern Company 2021 Annual Report Consolidated Statements of Stockholders’ Equity
For the Years Ended December 31, 2021, 2020, and 2019
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, 2018
Consolidated net income (loss)
Other comprehensive income (loss)
Issuance of equity units(*)
Stock issued
Stock-based compensation
Cash dividends of $2.4600 per share
Contributions from noncontrolling
interests
Distributions to noncontrolling
interests
Other
Balance at December 31, 2019
Consolidated net income (loss)
Other comprehensive income (loss)
Stock issued
Stock-based compensation
Cash dividends of $2.5400 per share
Contributions from noncontrolling
interests
Distributions to noncontrolling
interests
Purchase of membership interests
from noncontrolling interests
Sale of noncontrolling interests
Other
Balance at December 31, 2020
Consolidated net income (loss)
Other comprehensive income
Stock issued
Stock-based compensation
Cash dividends of $2.6200 per share
Contributions from noncontrolling
interests
Distributions to noncontrolling
interests
Other
1,035
—
—
—
19
—
—
—
—
—
1,054
—
—
4
—
—
—
—
—
—
—
1,058
—
—
3
—
—
—
—
—
(1) $ 5,164 $ 11,094
—
—
—
—
—
—
(198)
—
—
751
93
—
66
—
—
—
—
—
(in millions)
$(38) $ 8,706
4,739
—
—
—
—
(2,570)
—
—
—
—
—
—
—
—
—
(1)
—
—
—
—
—
—
—
—
—
—
(1)
—
—
—
—
—
—
—
—
—
—
—
5,257
—
—
11
—
—
—
—
21
11,734
—
—
63
44
—
—
—
—
—
—
—
—
5
(2)
(10)
—
—
(4)
(42)
—
—
—
—
—
—
—
—
—
(4)
—
—
2
10,877
3,119
—
—
—
(2,685)
—
—
—
—
—
5,268
—
—
11
—
—
11,834
—
—
62
62
—
11,311
(46)
2,393
—
—
—
—
—
—
—
— (2,777)
—
—
—
—
—
(8)
—
—
(1)
—
—
2
$ (203)
—
(118)
—
—
—
—
—
—
—
(321)
—
(75)
—
—
—
—
—
—
—
1
(395)
—
158
—
—
—
—
—
—
$ 4,316
(10)
—
—
—
—
—
$ 29,039
4,729
(118)
(198)
844
66
(2,570)
276
276
(327)
(1)
4,254
(31)
—
—
—
—
(327)
18
31,759
3,088
(75)
74
44
(2,685)
307
307
(271)
(271)
(65)
67
1
4,262
(99)
—
—
—
—
(60)
65
(12)
32,234
2,294
158
73
62
(2,777)
590
590
(351)
—
(351)
(7)
Balance at December 31, 2021
1,061
(1) $5,279 $11,950
$(47) $10,929
$(237)
$4,402
$32,276
(*) See Note 8 under “Equity Units” for additional information.
The accompanying notes are an integral part of these consolidated financial statements.
76
Southern Company 2021 Annual Report
Index to the Notes to Financial Statements
Note 1
Summary of Significant Accounting Policies
Note 2
Regulatory Matters
Note 3
Note 4
Contingencies, Commitments, and Guarantees
Revenue from Contracts with Customers
Note 5
Property, Plant, and Equipment
Note 6
Asset Retirement Obligations
Note 7
Consolidated Entities and Equity Method Investments
Note 8
Financing
Note 9
Leases
Note 10
Income Taxes
Note 11
Retirement Benefits
Note 12
Stock Compensation
Note 13
Fair Value Measurements
Note 14
Derivatives
Note 15
Acquisitions and Dispositions
Note 16
Segment and Related Information
78
91
112
118
122
125
129
132
139
148
154
175
177
184
192
195
77
Southern Company 2021 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 and 2, and is currently managing construction and start-up of Plant Vogtle Units 3
and 4, which are co-owned by Georgia Power. 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.
78
Southern Company 2021 Annual Report Notes to Financial Statements
Recently Adopted Accounting Standards
In March 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 amendments in ASU 2020-04 are
elective and apply to all entities that have contracts, hedging relationships, and other transactions that reference LIBOR or another reference
rate expected to be discontinued. The new guidance (i) simplifies accounting analyses under current GAAP for contract modifications; (ii)
simplifies the assessment of hedge effectiveness and allows hedging relationships affected by reference rate reform to continue; and (iii)
allows 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 may elect to apply the amendments prospectively from March 12, 2020 through December 31, 2022 by accounting topic.
The Registrants have elected to apply the amendments to modifications of debt arrangements that meet the scope of ASU 2020-04.
The Registrants currently reference LIBOR for certain debt and hedging arrangements. In addition, certain provisions in PPAs at Southern
Power include references to LIBOR. Contract language has been, or is expected to be, incorporated into each of these agreements to
address the transition to an alternative rate for agreements that will be in place at the transition date. While no material impacts are
expected from modifications to the arrangements and effective hedging relationships are expected to continue, the Registrants will
continue to evaluate the provisions of ASU 2020–04 and the impacts of transitioning to an alternative rate, and the ultimate outcome of
the transition cannot be determined at this time. 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 2021, 2020, and 2019 were as follows:
2021
2020
2019
Alabama
Power
$504
478
527
Georgia
Power
$663
639
704
Mississippi
Power
(in millions)
$120
149
118
Southern
Power
Southern
Company Gas
$89
87
90
$239
237
183
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 2021, 2020,
and 2019 amounted to $258 million, $262 million, and $256 million, respectively, for Alabama Power and $906 million, $883 million, and
$760 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 Units 3 and 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:
2021
2020
2019
Mississippi
Power
Southern
Power
(in millions)
$9
4
3
$15
8
14
79
Southern Company 2021 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 $132 million, $141 million, and $177 million in 2021, 2020, and 2019, 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
$139 million, $139 million, and $174 million for 2021, 2020, and 2019, respectively. Included within these revenues were affiliate PPAs
accounted for as operating leases, which totaled $112 million, $115 million, and $116 million for 2021, 2020, and 2019, respectively.
See Note 9 for additional information.
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 2021, 2020, and 2019 were as follows:
2021
2020
2019
Alabama
Power
Georgia
Power
Southern
Power
Southern
Company Gas
(in millions)
$14
15
17
$108
108
99
$31
29
28
$29
29
31
In 2018, SNG purchased the natural gas lateral pipeline serving Plant McDonough Units 4 through 6 from Georgia Power at net book
value, as approved by the Georgia PSC. In 2020, SNG paid Georgia Power $142 million, which included $71 million contributed to SNG by
Southern Company Gas for its proportionate share. During the interim period, Georgia Power received a discounted shipping rate to reflect
the deferred consideration and SNG constructed an extension to the pipeline.
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 and $18 million, $26 million, and $64 million for Southern Power in 2021, 2020, and 2019, respectively.
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 $10 million, $9 million, and $9 million in 2021, 2020, and 2019, respectively. See Note 5 under “Joint
Ownership Agreements” for additional information.
Alabama Power and Georgia 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.
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
$28 million, $15 million, and $15 million for 2021, 2020, and 2019, 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.
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.
80
Southern Company 2021 Annual Report Notes to Financial Statements
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, non-derivatives, or normal sale derivatives. 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.
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.
81
Southern Company 2021 Annual Report Notes to Financial Statements
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 and for all wholesale 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. 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 (effective November 1, 2019); 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.
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.
82
Southern Company 2021 Annual Report Notes to Financial Statements
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 or
industry 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 full requirements cost-based MRA electric tariffs, which are subject to regulation by the FERC. The contracts
with these wholesale customers represented 14.3% of Mississippi Power’s total operating revenues in 2021 and are generally subject to
10-year rolling cancellation notices. Historically, these wholesale customers have acted as a group and any changes in contractual
relationships for one customer are likely to be followed by the other wholesale customers.
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, adjustments to reduce the value of inventories to
market value, 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 deferred and 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 deferred and 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 2021 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.
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.
83
Southern Company 2021 Annual Report Notes to Financial Statements
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 $119 million, $104 million, and
$114 million in 2021, 2020, and 2019, 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 Registrants in 2021, 2020, and 2019 was as follows:
2021
2020
2019
Southern
Company
Alabama
Power
Georgia
Power(*)
Mississippi
Power
Southern
Power
Southern
Company Gas
$ 282
230
202
$68
61
71
(in millions)
$190
138
103
$ —
1
—
$ 6
11
15
$ 18
18
13
(*) See Note 2 under “Georgia Power – Nuclear Construction” for information on the inclusion of a portion of construction costs related to Plant Vogtle Units 3
and 4 in Georgia Power’s rate base.
The average AFUDC composite rates for 2021, 2020, and 2019 for the traditional electric operating companies and the natural gas
distribution utilities were as follows:
Alabama Power
Georgia Power(*)
Mississippi Power
Southern Company Gas:
Atlanta Gas Light
Chattanooga Gas
Nicor Gas
2021
2020
2019
7.9%
7.2%
2.5%
7.7%
7.1%
0.1%
8.1%
6.9%
5.4%
7.7%
7.1%
0.7%
8.4%
6.9%
7.3%
7.8%
7.1%
2.3%
(*) Excludes AFUDC related to the construction of Plant Vogtle Units 3 and 4. See Note 2 under “Georgia Power – Nuclear Construction” for additional information.
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 value 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 value, or an estimate of
undiscounted future cash flows attributable to the asset group, as compared with the carrying value of the assets. If an impairment has
occurred, the amount of the impairment recognized is determined by either the amount of regulatory disallowance or by estimating the
fair value of the assets and recording a loss if the carrying value is greater than the fair value. For assets identified as held for sale, the
carrying value 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.
84
Southern Company 2021 Annual Report Notes to Financial Statements
Goodwill and Other Intangible Assets and Liabilities
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 and liabilities 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.
Goodwill is not amortized, but is subject to an annual impairment test during the fourth quarter of each year, or more frequently if
impairment indicators arise. Southern Company and Southern Company Gas each evaluated its goodwill in the fourth quarter 2021 and
determined no impairment was required. See Note 15 under “Southern Company” for information regarding impairments to goodwill and
other intangible assets recorded in 2019.
At December 31, 2021 and 2020, goodwill was as follows:
Southern Company
Southern Company Gas:
Gas distribution operations
Gas marketing services
Southern Company Gas total
Notes to Financial Statements
At December 31, 2021 and 2020, other intangible assets were as follows:
Goodwill
(in millions)
$5,280
$4,034
981
$5,015
Goodwill and Other Intangible Assets and Liabilities
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 and liabilities primarily relate to its 2016 acquisition by Southern Company.
At December 31, 2021
At December 31, 2020
Gross
Carrying
Amount
Accumulated
Amortization
(in millions)
Other
Intangible
Assets, Net
Gross
Carrying
Amount
Accumulated
Amortization
(in millions)
Other
Intangible
Assets, Net
In addition to these items, Southern Company’s goodwill and other intangible assets also relate to its 2016 acquisition of PowerSecure.
Southern Company
Other intangible assets subject
Goodwill is not amortized, but is subject to an annual impairment test during the fourth quarter of each year, or more frequently if
to amortization:
impairment indicators arise. Southern Company and Southern Company Gas each evaluated its goodwill in the fourth quarter 2021 and
Customer relationships
$ 77
determined no impairment was required. See Note 15 under “Southern Company” for information regarding impairments to goodwill and
33
Trade names
other intangible assets recorded in 2019.
Storage and transportation contracts(*)
—
PPA fair value adjustments
301
At December 31, 2021 and 2020, goodwill was as follows:
1
Other
Goodwill
(in millions)
$412
$5,280
$ (150)
(38)
—
(109)
(10)
$(135)
(31)
(64)
(89)
(9)
$ 212
64
—
390
11
$212
64
64
390
10
$ 62
26
—
281
1
Total other intangible assets subject
$ (307)
$(328)
$ 677
$740
$370
Other intangible assets not subject
to amortization
Southern Company
Southern Company Gas:
to amortization:
Federal Communications Commission licenses
Gas distribution operations
Gas marketing services
Total other intangible assets
Southern Company Gas total
75
$ 752
—
$ (307)
75
$445
75
$815
—
$(328)
$4,034
75
981
$487
$5,015
Southern Power
At December 31, 2021 and 2020, other intangible assets were as follows:
Other intangible assets subject
to amortization:
PPA fair value adjustments
Southern Company Gas
Other intangible assets subject
At December 31, 2021
At December 31, 2020
$ 390
Gross
Carrying
Amount
$ (109)
Accumulated
Amortization
(in millions)
$281
Other
Intangible
Assets, Net
$390
Gross
Carrying
Amount
$ (89)
Accumulated
Amortization
(in millions)
$301
Other
Intangible
Assets, Net
Other intangible assets subject
Southern Company
to amortization:
Gas marketing services
to amortization:
Customer relationships
Customer relationships
Trade names
Trade names
Storage and transportation contracts(*)
Storage and transportation contracts(*)
PPA fair value adjustments
Other
Total other intangible assets subject
Wholesale gas services
to amortization
Total other intangible assets subject
$ 156
$ 212
26
64
—
390
11
$ 182
—
$ (130)
$ (150)
(15)
(38)
—
—
(109)
(10)
$ (145)
$ 26
$ 62
11
26
—
281
1
$ 37
—
$156
$212
26
64
64
390
10
$246
64
$(119)
$(135)
(12)
(31)
(64)
(89)
(9)
$(195)
(64)
$ 37
$ 77
14
33
—
301
1
$ 51
—
(*) See Note 15 under “Southern Company Gas” for information regarding the sale of Sequent.
to amortization
$ 677
$ (307)
$370
$740
$(328)
$412
75
$ 752
—
$ (307)
75
$445
75
$815
—
$(328)
75
$487
Southern Company 2021 Annual Report
85
$ 390
$ (109)
$281
$390
$ (89)
$301
Other intangible assets not subject
to amortization:
Federal Communications Commission licenses
Total other intangible assets
Southern Power
Other intangible assets subject
to amortization:
PPA fair value adjustments
Southern Company Gas
Other intangible assets subject
to amortization:
Gas marketing services
Customer relationships
Trade names
Wholesale gas services
Storage and transportation contracts(*)
Total other intangible assets subject
$ 156
26
—
$ (130)
(15)
—
$ 26
11
—
$156
26
64
$(119)
(12)
(64)
$ 37
14
—
to amortization
$ 182
$ (145)
$ 37
$246
$(195)
$ 51
(*) See Note 15 under “Southern Company Gas” for information regarding the sale of Sequent.
Southern Company 2021 Annual Report
85
Notes to Financial Statements
Amortization associated with other intangible assets in 2021, 2020, and 2019 was as follows:
Southern Company(a)
Southern Power(b)
Southern Company Gas:
Gas marketing services
Wholesale gas services(b)
Southern Company Gas total
2021
$44
20
$15
—
$15
2020
(in millions)
$49
20
$17
2
$19
2019
$61
19
$23
8
$31
(a) Includes $20 million, $22 million, and $27 million in 2021, 2020, and 2019, respectively, recorded as a reduction to operating revenues.
(b) Recorded as a reduction to operating revenues.
At December 31, 2021, the estimated amortization associated with other intangible assets for the next five years is as follows:
Southern Company
Southern Power
Southern Company Gas
2022
2023
$39
20
11
$37
20
9
2024
(in millions)
$35
20
7
2025
2026
$32
20
6
$27
20
3
Intangible liabilities of $91 million recorded under acquisition accounting for transportation contracts at Southern Company Gas were fully
amortized at December 31, 2019.
Acquisition Accounting
At the time of an acquisition, management will assess whether acquired assets and activities meet the definition of a business.
For acquisitions that meet the definition of a business, operating results from the date of acquisition are included in the acquiring entity’s
financial statements. The purchase price, including any contingent consideration, is allocated based on the fair value of the identifiable assets
acquired and liabilities assumed (including any intangible assets). 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
market prices, and expected asset lives. Any due diligence or transition costs incurred for potential or successful acquisitions are expensed
as incurred.
Historically, contingent consideration primarily 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.
86
Southern Company 2021 Annual Report Notes to Financial Statements
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.
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:
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
December
31, 2021
December
31, 2020
(in millions)
$1,798
$1,065
2
29
$1,829
2
—
$1,068
Southern
Power
December
31, 2021
(in millions)
$107
—
29
$135
Southern
Company Gas
December
31, 2021
December
31, 2020
(in millions)
$45
2
—
$48
$17
2
—
$19
(a) For Southern Power, reflects restricted cash of $19 million related to tax equity contributions restricted until the Garland battery energy storage facility
achieves final contracted capacity and $10 million held to fund estimated construction completion costs at the Deuel Harvest wind facility. See Note 15
under “Southern Power” for additional information. For Southern Company Gas, reflects restricted cash held as collateral for workers’ compensation, life
insurance, and long-term disability insurance.
(b) Total may not add due to rounding.
Storm Damage Reserves
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 additional accruals of $65 million, $100 million, and $84 million in 2021, 2020, and 2019, respectively.
In accordance with their respective state PSC orders, the traditional electric operating companies accrued the following amounts related to
storm damage recovery in 2021, 2020, and 2019:
2021
2020
2019
Southern
Company(a)(b)
Alabama
Power(a)
Georgia
Power
Mississippi
Power(b)
$286
326
170
(in millions)
$ 75
112
139
$213
213
30
$(2)
1
1
(a) Includes $39 million applied in 2019 to Alabama Power’s NDR from its remaining excess deferred income tax regulatory liability balance in accordance with
an Alabama PSC order.
(b) Mississippi Power’s net accrual includes carrying costs, as well as amortization of related excess deferred income tax benefits.
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.
87
Southern Company 2021 Annual Report Notes to Financial Statements
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, 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 WACOG 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, 2021, the Nicor Gas LIFO inventory balance was $166 million. Based on the average cost of gas purchased in
December 2021, the estimated replacement cost of Nicor Gas’ inventory at December 31, 2021 was $470 million.
Southern Company Gas’ gas marketing services, wholesale gas services (until the sale of Sequent on July 1, 2021), and all other segments
record inventory at LOCOM, with cost determined on a WACOG basis. For these segments, Southern Company Gas evaluates the weighted
average cost of its natural gas inventories against market prices to determine whether any declines in market prices below the WACOG
are other than temporary. For any declines considered to be other than temporary, Southern Company Gas records LOCOM adjustments to
cost of natural gas to reduce the value of its natural gas inventories to market value. LOCOM adjustments for wholesale gas services were
$1 million, $1 million, and $21 million during 2021, 2020, and 2019, respectively, and were immaterial for all of Southern Company Gas’
other segments.
Energy Marketing Receivables and Payables
Prior to the sale of Sequent on July 1, 2021, Southern Company Gas’ wholesale gas services provided services to retail gas marketers,
wholesale gas marketers, utility companies, and industrial customers. These counterparties utilized netting agreements that enabled
wholesale gas services to net receivables and payables by counterparty upon settlement. Southern Company Gas’ wholesale gas services
also netted across product lines and against cash collateral, provided the netting and cash collateral agreements included such provisions.
While the amounts due from, or owed to, wholesale gas services’ counterparties were settled net, they were recorded on a gross basis in
the balance sheets as energy marketing receivables and energy marketing payables.
Southern Company Gas’ wholesale gas services used 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 was most often in the form of cash or letters of credit from an investment-grade financial institution, but could also
include cash or U.S. government securities held by a trustee. When more than one derivative transaction with the same counterparty was
outstanding and a legally enforceable netting agreement existed with that counterparty, the “net” mark-to-market exposure represented a
reasonable measure of Southern Company Gas’ credit risk with that counterparty. Southern Company Gas’ wholesale gas services also used
other netting agreements with certain counterparties with whom it conducted significant transactions.
88
Southern Company 2021 Annual Report Notes to Financial Statements
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.
See Note 2 for information regarding recovery of incremental bad debt expense related to the COVID-19 pandemic at certain of the
traditional electric operating companies and natural gas distribution utilities.
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
16 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, 2021.
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.
Prior to the sale of Sequent on July 1, 2021, wholesale gas services purchased natural gas for storage when the market price paid to buy
and transport natural gas plus the cost to store and finance the natural gas was less than the market price that could be received in the
future, resulting in positive net natural gas revenues. NYMEX futures and OTC contracts were used to sell natural gas at that future price to
89
Southern Company 2021 Annual Report Notes to Financial Statements
substantially protect the natural gas revenues that would ultimately be realized when the stored natural gas was sold. 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 recorded in natural gas revenues on the statements of income 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.
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, 2020
Current period change
Balance at December 31, 2021
Southern Power
Balance at December 31, 2020
Current period change
Balance at December 31, 2021
Southern Company Gas
Balance at December 31, 2020
Current period change
Balance at December 31, 2021
(*) May not add due to rounding.
Variable Interest Entities
Qualifying
Hedges
$ (209)
47
$(162)
$ (21)
22
1
$
$ (20)
6
$ (14)
Pension and
Other
Postretirement
Benefit Plans
(in millions)
Accumulated
Other
Comprehensive
Income (Loss)(*)
$(187)
111
$ (76)
$ (47)
18
$ (29)
$
(2)
40
$ 38
$(395)
158
$(237)
$ (67)
40
$ (27)
$ (22)
46
$ 24
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.
At December 31, 2020, Alabama Power had a wholly-owned trust to issue preferred securities; however, since Alabama Power was not
considered the primary beneficiary of the trust, the related investment at December 31, 2020 is reflected as other investments and the
related loan from the trust is reflected as long-term debt in Alabama Power’s balance sheet. See Note 8 under “Long-term Debt” for
additional information.
90
Southern Company 2021 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, 2021 and 2020 are provided in the following tables:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Company Gas
At December 31, 2021
AROs(a)(u)
Retiree benefit plans(b)(u)
Remaining net book value of retired assets(c)
Deferred income tax charges(d)
Under recovered regulatory clause revenues(e)
Environmental remediation(f)(u)
Loss on reacquired debt(g)
Vacation pay(h)(u)
Regulatory clauses(i)
Storm damage(j)
Long-term debt fair value adjustment(k)
Nuclear outage(l)
Software and cloud computing costs(m)
Kemper County energy facility assets, net(n)
Plant Daniel Units 3 and 4(o)
Other regulatory assets(p)
Deferred income tax credits(d)
Other cost of removal obligations(a)
Customer refunds(q)
Fuel-hedging (realized and unrealized) gains(r)
Storm/property damage reserves(s)
Over recovered regulatory clause revenues(e)
Other regulatory liabilities(t)
Total regulatory assets (liabilities), net
At December 31, 2020
AROs(a)(u)
Retiree benefit plans(b)(u)
Remaining net book value of retired assets(c)
Deferred income tax charges(d)
Environmental remediation(f)(u)
Loss on reacquired debt(g)
Storm damage(j)
Vacation pay(h)(u)
Under recovered regulatory clause revenues(e)
Regulatory clauses(i)
Nuclear outage(l)
Long-term debt fair value adjustment(k)
Kemper County energy facility assets, net(n)
Plant Daniel Units 3 and 4(o)
Software and cloud computing costs(m)
Other regulatory assets(p)
Deferred income tax credits(d)
Other cost of removal obligations(a)
Over recovered regulatory clause revenues(e)
Storm/property damage reserves(s)
Customer refunds(q)
Other regulatory liabilities(t)
Total regulatory assets (liabilities), net
(in millions)
$ 3,866
962
455
555
—
35
231
102
—
48
—
34
33
—
—
29
(2,537)
278
(8)
(72)
—
(59)
(24)
$ 3,928
$ 3,457
1,647
527
531
41
248
262
104
—
—
40
—
—
—
12
56
(2,805)
212
(44)
—
(6)
(30)
$ 4,252
$ 1,576
747
574
240
225
—
42
81
142
—
—
41
35
—
—
38
(1,968)
(192)
(181)
(50)
(103)
(1)
(29)
$ 1,217
$ 1,470
1,265
632
235
—
47
—
80
58
142
61
—
—
—
17
35
(2,016)
(335)
(46)
(77)
(50)
(37)
$ 1,481
$ 5,685
2,998
1,050
829
806
302
281
207
142
97
79
75
73
35
28
168
(5,636)
(1,826)
(189)
(176)
(133)
(63)
(121)
$ 4,711
$ 5,147
4,958
1,183
801
310
304
262
207
185
142
101
92
50
32
31
174
(6,016)
(1,999)
(185)
(81)
(56)
(149)
$ 5,493
$ 236
145
21
31
49
—
6
10
—
49
—
—
—
35
28
7
(288)
(195)
—
(54)
(30)
—
(4)
$ 46
$ 212
238
24
32
—
6
—
10
52
—
—
—
50
32
—
4
(320)
(194)
—
(4)
—
(6)
$ 136
$
—
95
—
—
532
267
2
14
—
—
79
—
5
—
—
94
(816)
(1,683)
—
—
—
(3)
(57)
$ (1,471)
$
—
187
—
—
269
3
—
13
75
—
—
92
—
—
2
79
(847)
(1,649)
(95)
—
—
(54)
$ (1,925)
91
Southern Company 2021 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 53 years for Alabama Power,
60 years for Georgia Power, 55 years for Mississippi Power, and 80 years for Southern Company Gas. AROs and cost of removal obligations will be settled
and trued up following completion of the related activities. Effective January 1, 2020, Georgia Power is recovering CCR AROs, including past under
recovered costs and estimated annual compliance costs, over three-year periods ending December 31, 2022, 2023, and 2024 through its ECCR tariff, as
discussed further under “Georgia Power – Rate Plans” herein. See Note 6 for additional information on AROs.
(b) Recovered and amortized over the average remaining service period, which may range up to 13 years for Alabama Power, Georgia Power, and Mississippi
Power and up to 14 years for 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 Units 8, 9, and 10 ($533 million at December 31, 2021) being amortized over
remaining periods not exceeding 16 years (through 2037).
Georgia Power: Net book values of Plant Hammond Units 1 through 4 and Plant Branch Units 3 and 4 (totaling $445 million at December 31, 2021) are
being amortized over remaining periods of between two and 14 years (between 2023 and 2035) and the net book values of Plant Branch Unit 2, Plant
McIntosh Unit 1, and Plant Mitchell Unit 3 (totaling $10 million at December 31, 2021) are being amortized through 2022.
Mississippi Power: Represents net book value of certain environmental compliance projects associated with Plant Watson and Plant Greene County being
amortized over a 10-year period through 2030. See “Mississippi Power – Environmental Compliance Overview Plan” herein for additional information.
(d) Deferred income tax charges are recovered and deferred income tax credits are amortized over the related property lives, which may range up to
53 years for Alabama Power, 60 years for Georgia Power, 55 years for Mississippi Power, and 80 years for Southern Company Gas. See Note 10 for
additional information. Included in the deferred income tax charges are amounts ($7 million and $4 million for Alabama Power and Georgia Power,
respectively, at December 31, 2021) for the retiree Medicare drug subsidy, which are being recovered and amortized through 2027 and 2022 for Alabama
Power and Georgia Power, respectively. 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 are being recovered and amortized ratably over the related property lives.
Georgia Power: Related amounts at December 31, 2021 include $145 million of deferred income tax assets related to CWIP for Plant Vogtle Units 3 and 4
and approximately $220 million of deferred income tax liabilities. The recovery of deferred income tax assets related to CWIP for Plant Vogtle Units 3 and 4 is
expected to be determined in a future regulatory proceeding. Effective January 1, 2020, the deferred income tax liabilities are being amortized through 2022.
Mississippi Power: Related amounts at December 31, 2021 include $46 million of retail deferred income tax liabilities generally being amortized over three
years (through 2023). See “Mississippi Power – 2019 Base Rate Case” herein for additional information.
Southern Company Gas: Related amounts at December 31, 2021 include $3 million of deferred income tax liabilities 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 or returned within eight years. Recovery periods could change based on
several factors including changes in cost estimates, load forecasts, and timing of rate adjustments. 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, 2021, $24 million is being amortized over a three-year period through 2023 and the remaining $25 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 four 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. The significant change during 2021 was primarily driven by an increase in the cost of gas purchased in February 2021
resulting from Winter Storm Uri.
(f) Georgia Power is recovering $12 million annually for environmental remediation under the 2019 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.
(g) Recovered over either the remaining life of the original issue or, if refinanced, over the remaining life of the new issue. At December 31, 2021, the remaining
amortization periods do not exceed 26 years for Alabama Power, 31 years for Georgia Power, 20 years for Mississippi Power, and six years for Southern
Company Gas.
(h) Recorded as earned by employees and recovered as paid, generally within one year. Includes both vacation and banked holiday pay, if applicable.
(i) Will be amortized concurrently with the effective date of Alabama Power’s next depreciation study, which is expected to occur no later than 2023.
(j) Georgia Power is recovering approximately $213 million annually for storm damage under the 2019 ARP. See “Georgia Power – Storm Damage Recovery”
herein for additional information. Mississippi Power’s balance represents deferred storm costs associated with Hurricanes Ida and Zeta to be recovered
through PEP over a period to be determined in Mississippi Power’s 2022 PEP proceeding. See “Mississippi Power – System Restoration Rider” herein for
additional information. Also see Note 1 under “Storm Damage Reserves” for additional information.
(k) Recovered over the remaining lives of the original debt issuances at acquisition, which range up to 17 years at December 31, 2021.
(l) 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.
(m) 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. See “Alabama Power – Software Accounting Order” herein for
additional information. For Georgia Power, the recovery period will be determined in its next base rate case. For Southern Company Gas, costs will be
amortized ratably beginning in July 2022 over the life of the related software, which ranges up to 10 years.
(n) Includes $44 million of regulatory assets and $9 million of regulatory liabilities at December 31, 2021. The retail portion includes $33 million of regulatory
assets and $9 million of regulatory liabilities that are expected to be fully amortized by 2023 and 2024, respectively. The wholesale portion includes
$11 million of regulatory assets that are expected to be fully amortized by 2029.
92
Southern Company 2021 Annual Report Notes to Financial Statements
(o) 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, 2021, consists of the $19 million retail portion, which is being amortized over the remaining life of the units through 2041,
and the $9 million wholesale portion, which is expected to be amortized over a period to be determined in a future wholesale rate filing.
(p) Except as otherwise noted, comprised of numerous immaterial components with remaining amortization periods generally not exceeding 23 years for
Alabama Power, 10 years for Georgia Power, six years for Mississippi Power, and 20 years for Southern Company Gas at December 31, 2021. Balances at
December 31, 2021 and 2020 include deferred COVID-19 costs (except for Alabama Power), as discussed further under “Deferral of Incremental COVID-19
Costs” for each applicable Registrant herein.
(q) Primarily includes approximately $181 million and $50 million at December 31, 2021 and 2020, respectively, for Alabama Power and $5 million at
December 31, 2021 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.
(r) 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 three years for Mississippi Power. Immaterial amounts at December 31, 2020 are
included in other regulatory assets and liabilities.
(s) Amortized as related expenses are incurred. See “Alabama Power – Rate NDR” and “Mississippi Power – System Restoration Rider” herein for additional
information.
(t) Comprised of numerous immaterial components with remaining amortization periods generally not exceeding 16 years for Alabama Power, 11 years for
Georgia Power, three years for Mississippi Power, and 20 years for Southern Company Gas at December 31, 2021.
(u) 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.
Certificates of Convenience and Necessity
In August 2020, the Alabama PSC issued its order regarding Alabama Power’s 2019 petition for a CCN, which authorized Alabama Power
to (i) construct an approximately 720-MW combined cycle facility at Alabama Power’s Plant Barry (Plant Barry Unit 8) that is expected to
be placed in service by the end of 2023, (ii) complete the acquisition of the Central Alabama Generating Station, which occurred in August
2020, (iii) purchase approximately 240 MWs of combined cycle generation under a long-term PPA, which began in September 2020, and
(iv) pursue up to approximately 200 MWs of cost-effective demand-side management and distributed energy resource programs. Alabama
Power’s petition for a CCN was predicated on the results of Alabama Power’s 2019 IRP provided to the Alabama PSC, which identified an
approximately 2,400-MW resource need for Alabama Power, driven by the need for additional winter reserve capacity. See Note 15 under
“Alabama Power” for additional information on the acquisition of the Central Alabama Generating Station.
The Alabama PSC authorized the recovery of actual costs for the construction of Plant Barry Unit 8 up to 5% above the estimated in-service
cost of $652 million. In so doing, it recognized the potential for developments that could cause the project costs to exceed the capped
amount, in which case Alabama Power would provide documentation to the Alabama PSC to explain and justify potential recovery of the
additional costs. At December 31, 2021, project expenditures associated with Plant Barry Unit 8 included in CWIP totaled approximately
$304 million.
The Alabama PSC further directed that additional solar generation of approximately 400 MWs proposed in the 2019 CCN petition, coupled
with battery energy storage systems (solar/battery systems), be evaluated under an existing Renewable Generation Certificate (RGC). The
contracts originally proposed expired in July 2020. See “Renewable Generation Certificate” herein for additional information.
Alabama Power expects to recover costs associated with Plant Barry Unit 8 pursuant to its Rate CNP New Plant. Alabama Power is
recovering all costs associated with the Central Alabama Generating Station through the inclusion in Rate RSE of revenues from the existing
power sales agreement and, on expiration of that agreement, expects to recover costs pursuant to Rate CNP New Plant. The recovery of
costs associated with laws, regulations, and other such mandates directed at the utility industry are expected to be recovered through
Rate CNP Compliance. Alabama Power expects to recover the capacity-related costs associated with the PPAs through its Rate CNP PPA. In
addition, fuel and energy-related costs are expected to be recovered through Rate ECR. Any remaining costs associated with Plant Barry Unit
8 and the acquisition of the Central Alabama Generating Station are expected to be recovered through Rate RSE.
On September 23, 2021, Alabama Power entered into an agreement to acquire all of the equity interests in Calhoun Power Company,
LLC, which owns and operates a 743-MW winter peak, simple-cycle, combustion turbine generation facility in Calhoun County, Alabama
(Calhoun Generating Station). The total purchase price associated with the acquisition is approximately $180 million, subject to working
capital adjustments. The completion of the acquisition is subject to the satisfaction and waiver of certain conditions, including, among other
customary conditions, approval by the Alabama PSC and the FERC.
93
Southern Company 2021 Annual Report Notes to Financial Statements
On October 28, 2021, Alabama Power filed a petition for a CCN with the Alabama PSC to procure additional generating capacity through
this acquisition. Completion of the acquisition and certain operating conditions would enable Alabama Power to retire Plant Barry Unit 5
as early as 2023. A decision from the Alabama PSC is expected by the third quarter 2022. Pending certification, Alabama Power expects to
recover costs associated with the Calhoun Generating Station through its existing rate structure, primarily Rate CNP New Plant, Rate CNP
Compliance, Rate ECR, and Rate RSE.
Alabama Power expects to complete the transaction by September 30, 2022; however, the ultimate outcome of these matters cannot be
determined at this time.
Renewable Generation Certificate
Through the issuance of a RGC, the Alabama PSC has authorized Alabama Power to procure up to 500 MWs of renewable capacity and
energy by September 16, 2027 and to market the related energy and environmental attributes to customers and other third parties.
Through December 31, 2021, Alabama Power has procured approximately 250 MWs through five projects approved under the RGC.
Alabama Power owns two of the projects, totaling 18 MWs, with the remaining MWs expected to be served through three PPAs, two of
which will commence in the first quarter 2024.
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 both
December 31, 2021 and 2020, Alabama Power’s equity ratio was approximately 51.6%.
Effective for January 2019, the Alabama PSC approved modifications to Rate RSE. These modifications reduced the top of the allowed WCER
range from 6.21% to 6.15% and modified the refund mechanism applicable to prior year actual results to allow Alabama Power to retain
a portion of the revenue that causes the actual WCER for a given year to exceed the allowed range. These modifications were designed to
position Alabama Power to address the growing pressure on its credit quality resulting from the Tax Reform Legislation, without increasing
retail rates under Rate RSE in the near term.
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%. There is no provision for additional customer billings should the actual retail return fall below
the WCER range.
In conjunction with these modifications to Rate RSE, Alabama Power consented to a moratorium on any upward adjustments under Rate RSE
for 2019 and 2020 and to return $50 million to customers through bill credits in 2019. Retail rates under Rate RSE remained unchanged for
2019 and 2020 and increased by 4.09%, or approximately $228 million annually, effective with the billing month of January 2021.
At December 31, 2019, 2020, and 2021, Alabama Power’s WCER exceeded 6.15%, resulting in Alabama Power establishing a current regulatory
liability of $53 million, $50 million, and $181 million, respectively, for Rate RSE refunds. The 2019 and 2020 refunds were issued to customers
through bill credits in April of the following year. In accordance with an Alabama PSC order issued on February 1, 2022, Alabama Power will
apply $126 million of the 2021 refund to reduce the Rate ECR under recovered balance and the remaining $55 million will be refunded to
customers through bill credits in July 2022. See “Rate ECR” herein for additional information.
On December 1, 2021, Alabama Power made its required annual Rate RSE submission to the Alabama PSC of projected data for calendar year
2022. Projected earnings were within the specified range; therefore, retail rates under Rate RSE remain unchanged for 2022.
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 2019 through 2021.
See “Certificates of Convenience and Necessity” herein for additional information.
94
Southern Company 2021 Annual Report Notes to Financial Statements
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 factor will have no significant effect on Southern Company’s or Alabama Power’s revenues or net income
but will affect annual cash flow. No adjustments to Rate CNP PPA occurred during the period 2019 through 2021 and no adjustment is
expected for 2022. At December 31, 2021 and 2020, Alabama Power had an under recovered Rate CNP PPA balance of $84 million and
$58 million, respectively, which 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 factor 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 2019, 2020, and 2021, Alabama Power submitted calculations associated with its cost of complying with governmental
mandates for the following calendar year, as provided under Rate CNP Compliance. The 2019 filing reflected a projected over recovered
retail revenue requirement, which resulted in a rate decrease of approximately $68 million that became effective for the billing month
of January 2020. Both the 2020 and 2021 filings reflected a projected under recovered retail revenue requirement of approximately
$59 million. In December 2020 and on December 7, 2021, the Alabama PSC issued consent orders that Alabama Power leave the 2020
Rate CNP Compliance factors in effect for 2021 and 2022, respectively, with any prior year under collected amount deemed recovered
before any current year amounts are recovered. Any remaining under recovered amount will be reflected in the 2022 filing.
At December 31, 2021, Alabama Power had an under recovered Rate CNP Compliance balance of $16 million included in other regulatory
assets, deferred on the balance sheet. At December 31, 2020, Alabama Power had an over recovered Rate CNP Compliance balance of
$28 million included in other regulatory liabilities, current on the balance sheet.
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 operating cash
flows. The Alabama PSC may approve billing rates under Rate ECR of up to 5.910 cents per KWH.
In 2019, the Alabama PSC approved a decrease to Rate ECR from 2.353 cents per KWH to 2.160 cents per KWH, equal to 1.82%, or
approximately $102 million annually, that became effective for the billing month of January 2020.
In October 2020, Alabama Power reduced its over-collected fuel balance by $94 million in accordance with an August 2020 Alabama PSC
order and returned that amount to customers in the form of bill credits.
In December 2020, the Alabama PSC approved a decrease to Rate ECR from 2.160 cents per KWH to 1.960 cents per KWH, equal to 1.84%,
or approximately $103 million annually, that became effective for the billing month of January 2021.
On December 7, 2021, the Alabama PSC issued a consent order that Alabama Power leave the 2021 Rate ECR factors in effect for 2022.
The rate will adjust to 5.910 cents per KWH in January 2023 absent a further order from the Alabama PSC.
At December 31, 2021, Alabama Power’s under recovered fuel costs totaled $126 million and is included in other regulatory assets, deferred
on the balance sheet. In accordance with an Alabama PSC order issued on February 1, 2022, Alabama Power will apply $126 million of its
2021 Rate RSE refund to reduce the Rate ECR under recovered balance. See “Rate RSE” herein for additional information. At December 31,
2020, Alabama Power’s over recovered fuel costs totaled $18 million and is included in other regulatory liabilities, current on the balance
sheet. 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.
95
Southern Company 2021 Annual Report Notes to Financial Statements
Software Accounting Order
In 2019, the Alabama PSC approved an accounting order that authorizes Alabama Power to establish a regulatory asset for operations and
maintenance costs associated with software implementation projects. The regulatory asset will be amortized ratably over the life of the
related software. At December 31, 2021 and 2020, the regulatory asset balance totaled $35 million and $17 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. On September 9, 2021, the Mississippi PSC issued an order confirming the conclusion of its review of Mississippi
Power’s 2021 IRP with no deficiencies identified. Mississippi Power’s 2021 IRP 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. The Plant Greene County unit retirements identified by Mississippi Power require the completion of transmission and system
reliability improvements, as well as agreement by Alabama Power. Alabama Power will continue to monitor the status of the transmission
and system reliability improvements. Currently, Alabama Power plans to retire Plant Greene County Units 1 and 2 at the dates indicated.
The ultimate outcome of this matter cannot be determined at this time.
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 24-month period. 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. Absent further Alabama PSC approval, the
maximum total Rate NDR charge consisting of both components is $10 per month per non-residential customer account and $5 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. The order allows for reliability-related expenditures to be charged against the additional accruals when
the NDR balance exceeds $75 million. Alabama Power may designate a portion of the NDR to reliability-related expenditures as a part of
an annual budget process for the following year or during the current year for identified unbudgeted reliability-related expenditures that
are incurred. Accruals that have not been designated can be used to offset storm charges. Additional accruals to the NDR enhance Alabama
Power’s ability to mitigate the financial effects of future natural disasters, promote system reliability, and offset costs retail customers would
otherwise bear. Alabama Power made additional accruals of $65 million, $100 million, and $84 million in 2021, 2020, and 2019, respectively.
Alabama Power collected approximately $6 million, $5 million, and $16 million in 2021, 2020, and 2019, respectively, under Rate NDR.
At December 31, 2021 and 2020, the NDR balance was $103 million and $77 million, respectively, and is included in other regulatory
liabilities, deferred on the balance sheets. Beginning with June 2022 billings, the reserve establishment charge will be suspended and the
reserve maintenance charge will be activated as a result of the NDR balance exceeding $75 million. Alabama Power expects to collect
$8 million in 2022 and approximately $3 million annually beginning in 2023 under Rate NDR unless the NDR balance falls below $50 million.
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.
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.
Georgia Power
Georgia Power’s revenues from regulated retail operations are collected through various rate mechanisms subject to the oversight of the
Georgia PSC. Georgia Power currently recovers its costs from the regulated retail business through the 2019 ARP, which includes traditional
base tariffs, Demand-Side Management (DSM) tariffs, the ECCR tariff, and Municipal Franchise Fee (MFF) tariffs. In addition, financing
costs on certified construction costs of Plant Vogtle Units 3 and 4 are being collected through the NCCR tariff and fuel costs are collected
through a fuel cost recovery tariff, both under separate regulatory proceedings.
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Southern Company 2021 Annual Report Notes to Financial Statements
See “Plant Vogtle Unit 3 and Common Facilities Rate Proceeding” 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 will become effective the month after Unit 3 is placed in service. As costs are included in retail base rates, the related financing costs will
no longer be recovered through the NCCR tariff. See “Nuclear Construction” herein for additional information on Plant Vogtle Units 3 and 4.
Rate Plans
2019 ARP
In 2019, the Georgia PSC voted to approve the 2019 ARP, under which Georgia Power increased its rates on January 1, 2020. In December
2020 and on November 18, 2021, the Georgia PSC approved tariff adjustments effective January 1, 2021 and 2022, respectively. Details of
tariff adjustments are provided in the table below:
Tariff
Traditional base
ECCR(*)
DSM
MFF
Total
2020
2021
2022
(in millions)
$ 120
2
(15)
4
$ 111
$ —
318
12
12
$ 342
$ 192
(12)
(25)
2
$ 157
(*) Effective January 1, 2020, CCR AROs are being recovered through the ECCR tariff.
In 2019, the Georgia PSC voted to approve Georgia Power’s modified triennial IRP (Georgia Power 2019 IRP), including Georgia Power’s
proposed environmental compliance strategy associated with ash pond and certain landfill closures and post-closure care in compliance
with the CCR Rule and the related state rule. In the 2019 ARP, the Georgia PSC approved recovery of the estimated under recovered
balance of these compliance costs at December 31, 2019 over a three-year period ending December 31, 2022 and recovery of estimated
compliance costs for 2020, 2021, and 2022 over three-year periods ending December 31, 2022, 2023, and 2024, respectively, with recovery
of construction contingency beginning in the year following actual expenditure. The ECCR tariff is revised for actual expenditures and
updated estimates through annual compliance filings. Effective January 1, 2021 and 2022, Georgia Power adjusted its amortization of costs
associated with CCR AROs by an approximate decrease of $90 million and increase of $10 million, respectively, as approved by the Georgia
PSC in conjunction with Georgia Power’s annual compliance filings. See “Integrated Resource Plan” herein for additional information.
In February 2020, the Georgia PSC denied a motion for reconsideration filed by the Sierra Club regarding the Georgia PSC’s decision in the
2019 ARP allowing Georgia Power to recover compliance costs for CCR AROs. The Superior Court of Fulton County subsequently affirmed
the Georgia PSC’s decision and, on October 25, 2021, the Georgia Court of Appeals affirmed the Superior Court of Fulton County’s order.
On December 6, 2021, the Sierra Club filed a petition for writ of certiorari to the Georgia Supreme Court. The ultimate outcome of this
matter cannot be determined at this time. See Note 6 for additional information regarding Georgia Power’s AROs.
Under the 2019 ARP, Georgia Power’s retail ROE is set at 10.50%, and earnings will be evaluated against a retail ROE range of 9.50% to 12.00%.
Any retail earnings above 12.00% 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 2019 ARP, Georgia Power projects that its retail earnings will be below 9.50% for any calendar year, it
could 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,
2023 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 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 to refund to customers in 2022, subject to review and approval by the Georgia PSC.
Additionally, under the 2019 ARP and pursuant to the sharing mechanism approved in the 2013 ARP whereby two-thirds of any earnings
above the top of the allowed ROE range are shared with Georgia Power’s customers, (i) Georgia Power used 50% (approximately
$50 million) of the customer share of earnings above the band in 2018 to reduce regulatory assets and refunded 50% (approximately
$50 million) to customers in 2020 and (ii) Georgia Power agreed to forego its share of 2019 earnings in excess of the earnings band so 50%
(approximately $60 million) of all earnings over the 2019 band were refunded to customers in 2020 and 50% (approximately $60 million)
were used to reduce regulatory assets.
Georgia Power is required to file a general base rate case by July 1, 2022, in response to which the Georgia PSC would be expected to
determine whether the 2019 ARP should be continued, modified, or discontinued.
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Southern Company 2021 Annual Report Notes to Financial Statements
2013 ARP
Georgia Power’s retail ROE under the 2013 ARP was set at 10.95% and earnings were evaluated against a retail ROE range of 10.00% to
12.00%. Two-thirds of any earnings above 12.00% were to be directly refunded to customers, with the remaining one-third retained by
Georgia Power. In 2019 and 2018, Georgia Power’s retail ROE exceeded 12.00% and, under the modified sharing mechanism pursuant to
the 2019 ARP, Georgia Power reduced regulatory assets by a total of approximately $110 million and accrued approximately $110 million
for retail customer refunds through bill credits that were completed in 2020. See “2019 ARP” herein for additional information.
Plant Vogtle Unit 3 and Common Facilities Rate Proceeding
On June 15, 2021, Georgia Power filed an application with the Georgia PSC to adjust retail base rates to include the portion of costs related
to its investment in Plant Vogtle Unit 3 and Common Facilities previously deemed prudent by the Georgia PSC, as well as the related
costs of operation. On November 2, 2021, the Georgia PSC voted to approve Georgia Power’s application as filed, with the following
modifications pursuant to a stipulated agreement between Georgia Power and the staff of the Georgia PSC. Georgia Power will include
in rate base an allocation of $2.1 billion to Unit 3 and Common Facilities from the $3.6 billion of Plant Vogtle Units 3 and 4 previously
deemed prudent by the Georgia PSC and will recover the related depreciation expense through retail base rates effective the month after
Unit 3 is placed in service. Financing costs on the remaining portion of the total Unit 3 and the Common Facilities construction costs will
continue to be recovered through the NCCR tariff or deferred. Georgia Power will defer as a regulatory asset the remaining depreciation
expense (approximately $38 million annually) until Unit 4 costs are placed in retail base rates. In addition, the stipulated agreement
clarified that following the prudency review, the remaining amount to be placed in retail base rates will be net of the proceeds from the
Guarantee Settlement Agreement and will not be used to offset imprudent costs, if any.
The related increase in annual retail base rates of approximately $302 million also includes 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 production
tax credits, and will become effective the month after Unit 3 is placed in service. This increase is partially offset by a decrease in the NCCR
tariff of approximately $78 million effective January 1, 2022. As approved by the Georgia PSC, the increase in annual retail base rates will
be adjusted based on the actual in-service date of Plant Vogtle Unit 3.
See “Nuclear Construction” herein for additional information on Plant Vogtle Units 3 and 4.
Integrated Resource Plan
In 2021, as authorized in its 2019 IRP, Georgia Power requested and received certification from the Georgia PSC for 970 MWs of utility-
scale PPAs for solar generation resources, which are expected to be in operation by the end of 2023.
On January 31, 2022, Georgia Power filed its triennial IRP (2022 IRP). The filing included a request to decertify and retire Plant Wansley
Units 1 and 2 (926 MWs based on 53.5% ownership) by August 31, 2022; Plant Bowen Units 1 and 2 (1,400 MWs) by December 31, 2027;
and 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) by December 31, 2028. See Note 7 under “SEGCO” for additional information.
In the 2022 IRP, Georgia Power requested approval to reclassify the remaining net book value of Plant Wansley Units 1 and 2
(approximately $610 million at December 31, 2021), Plant Bowen Units 1 and 2 (approximately $937 million at December 31, 2021), and
Plant Scherer Unit 3 (approximately $622 million at December 31, 2021) and any remaining unusable materials and supplies inventories
upon each unit’s respective retirement dates to a regulatory asset, with recovery periods to be determined in future base rate cases.
In addition, the 2022 IRP includes requests for approval of the following:
O Capital, operations and maintenance, and CCR ARO costs associated with ash pond and landfill closures and post-closure care.
The recovery of these costs is expected to be determined in future base rate cases;
O Installation of environmental controls at Plant Bowen Units 3 and 4 (1,760 MWs) and Plant Scherer Units 1 and 2 (137 MWs based on
8.4% ownership) for compliance with ELG rules;
O Investments related to the hydro operations of Plants Sinclair (45 MWs), North Highlands (30 MWs), and Burton (6 MWs);
O Establishment of a request for proposals (RFP) process for 2,300 MWs of renewable resources by 2029. Georgia Power expects to
request an additional 3,700 MWs by 2035 through future IRP proceedings;
O Procurement of 1,000 MWs of Georgia Power-owned storage resources by 2030, including the development of a 265-MW battery
energy storage facility beginning in 2026;
O Related transmission costs necessary to support the proposed retirements and renewable resources previously described;
O Certification of six PPAs (including five affiliate PPAs with Southern Power that are also 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 approved
through the 2019 IRP; and
O Certification of approximately 88 MWs of wholesale capacity to be placed in retail rate base between January 1, 2024 and January 1, 2025.
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Southern Company 2021 Annual Report Notes to Financial Statements
A decision from the Georgia PSC on the 2022 IRP is expected in July 2022. The ultimate outcome of these matters cannot be determined at
this time.
Deferral of Incremental COVID-19 Costs
In April 2020 and June 2020, in response to the COVID-19 pandemic, the Georgia PSC approved orders directing Georgia Power to continue
its previous, voluntary suspension of customer disconnections through July 14, 2020 and to defer the resulting incremental bad debt as
a regulatory asset. In June 2020 and July 2020, the Georgia PSC approved orders establishing a methodology for identifying incremental
bad debt and allowing the deferral of other incremental costs associated with the COVID-19 pandemic. At December 31, 2020, the
incremental costs deferred totaled approximately $38 million (including approximately $23 million of incremental bad debt costs and
$15 million of other incremental costs). Since June 2021, Georgia Power has continued a review of bad debt amounts deferred under
the Georgia PSC-approved methodology, including consideration of actual amounts repaid by customers from arrears and installment
plans after the disconnection moratorium period ended. As a result, Georgia Power’s incremental costs deferred at December 31, 2021
totaled approximately $21 million, including an immaterial amount of incremental bad debt costs. The period over which these costs
will be recovered is expected to be determined in Georgia Power’s next base rate case. The ultimate outcome of this matter cannot be
determined at this time.
Fuel Cost Recovery
Georgia Power has established fuel cost recovery rates approved by the Georgia PSC. In May 2020, the Georgia PSC approved a
stipulation agreement among Georgia Power, the staff of the Georgia PSC, and certain intervenors to lower total fuel billings by
approximately $740 million over a two-year period effective June 1, 2020. In addition, Georgia Power further lowered fuel billings
by approximately $44 million under an interim fuel rider effective June 1, 2020 through September 30, 2020. 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,
on November 18, 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. Georgia Power continues to be allowed to adjust its fuel cost recovery
rates under an interim fuel rider prior to the next fuel case if the over recovered fuel balance exceeds $200 million. Georgia Power is
scheduled to file its next fuel case no later than February 28, 2023.
Georgia Power’s under recovered fuel balance totaled $410 million at December 31, 2021 and is included in other deferred charges
and assets on Southern Company’s balance sheet and deferred under recovered fuel clause revenues on Georgia Power’s balance sheet.
At December 31, 2020, Georgia Power’s over recovered fuel balance totaled $113 million and is included in other current liabilities on
Southern Company’s balance sheet and over recovered fuel clause revenues on Georgia Power’s balance sheet.
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.
Storm Damage Recovery
Georgia Power defers and recovers certain costs related to damages from major storms as mandated by the Georgia PSC. Beginning
January 1, 2020, Georgia Power is recovering $213 million annually under the 2019 ARP. At December 31, 2021 and 2020, the balance
in the regulatory asset related to storm damage was $48 million and $262 million, respectively, with $48 million and $213 million,
respectively, included in other regulatory assets, current on Southern Company’s balance sheets and regulatory assets – storm damage on
Georgia Power’s balance sheets and $49 million at December 31, 2020 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 financial statements.
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.
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Southern Company 2021 Annual Report Notes to Financial Statements
In connection with the EPC Contractor’s bankruptcy filing in March 2017, Georgia Power, acting for itself and as agent for the other
Vogtle Owners, entered into several transitional arrangements to allow construction to continue. In July 2017, Georgia Power, acting for
itself and as agent for the other Vogtle Owners, entered into the Vogtle Services Agreement, whereby Westinghouse provides facility
design and engineering services, procurement and technical support, and staff augmentation on a time and materials cost basis. The
Vogtle Services Agreement provides that it will continue until the start-up and testing of Plant Vogtle Units 3 and 4 are complete and
electricity is generated and sold from both units. The Vogtle Services Agreement is terminable by the Vogtle Owners upon 30 days’
written notice.
In October 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, executed the Bechtel Agreement, a cost
reimbursable plus fee arrangement, whereby Bechtel is reimbursed for actual costs plus a base fee and an at-risk fee, which is subject to
adjustment based on Bechtel’s performance against cost and schedule targets. Each Vogtle Owner is severally (not jointly) liable for its
proportionate share, based on its ownership interest, of all amounts owed to Bechtel under the Bechtel Agreement. The Vogtle Owners
may terminate the Bechtel Agreement at any time for their convenience, provided that the Vogtle Owners will be required to pay amounts
related to work performed prior to the termination (including the applicable portion of the base fee), certain termination-related costs,
and, at certain stages of the work, the applicable portion of the at-risk fee. Bechtel may terminate the Bechtel Agreement under certain
circumstances, including certain Vogtle Owner suspensions of work, certain breaches of the Bechtel Agreement by the Vogtle Owners,
Vogtle Owner insolvency, and certain other events.
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 end of the first quarter 2023 and the fourth quarter 2023, respectively, 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, 2021(b)
Remaining estimate to complete
(in millions)
$10,251
150
10,401
(8,442)
$ 1,959
(a) Includes approximately $590 million of costs that are not shared with the other Vogtle Owners and approximately $440 million of incremental costs under
the cost-sharing and tender provisions of the joint ownership agreements described below. Excludes financing costs expected to be capitalized through
AFUDC of approximately $375 million, of which $195 million had been accrued through December 31, 2021.
(b) Net of $1.7 billion received from Toshiba under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds.
Georgia Power estimates that its financing costs for construction of Plant Vogtle Units 3 and 4 will total approximately $3.4 billion,
of which $2.9 billion had been incurred through December 31, 2021.
As part of its ongoing processes, Southern Nuclear continues to evaluate cost and schedule forecasts on a regular basis to incorporate
current information available, particularly in the areas of engineering support, commodity installation, system turnovers and related test
results, and workforce statistics. Southern Nuclear establishes aggressive target values for monthly construction production and system
turnover activities, which are reflected in the site work plans.
In mid-March 2020, Southern Nuclear began implementing policies and procedures designed to mitigate the risk of transmission of
COVID-19 at the construction site, including worker distancing measures; isolating individuals who tested positive for COVID-19, showed
symptoms consistent with COVID-19, were being tested for COVID-19, or were in close contact with such persons; requiring self-
quarantine; and adopting additional precautionary measures. Since March 2020, the number of active cases at the site has fluctuated
consistent with the surrounding area and impacted productivity levels and pace of activity completion, with the site experiencing peaks
in the number of active cases in January 2021, August 2021, and January 2022. Georgia Power estimates the productivity impacts of the
COVID-19 pandemic have consumed approximately three to four months of schedule margin previously embedded in the site work plan
for Unit 3 and Unit 4. Georgia Power’s proportionate share of the estimated incremental cost associated with COVID-19 mitigation actions
and impacts on construction productivity is currently estimated to be between $160 million and $200 million and is included in the total
project capital cost forecast. The continuing effects of the COVID-19 pandemic could further disrupt or delay construction and testing
activities at Plant Vogtle Units 3 and 4.
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Southern Company 2021 Annual Report Notes to Financial Statements
During 2021, Southern Nuclear performed additional construction remediation work necessary to ensure quality and design standards
are met and support system turnovers necessary for Unit 3 hot functional testing, which was completed in July 2021, and fuel load.
As a result of Unit 3 challenges including, but not limited to, construction productivity, construction remediation work, the pace of
system turnovers, spent fuel pool repairs, and the timeframe and duration for hot functional and other testing, at the end of each of
the second and third quarters 2021, Southern Nuclear further extended certain milestone dates, including fuel load for Unit 3, from
those established in January 2021. Through the fourth quarter 2021, the project continued to face these and other challenges related
to the completion of documentation, including inspection records, necessary to submit the remaining ITAACs and begin fuel load. As a
result, at the end of the fourth quarter 2021, Southern Nuclear further extended certain milestone dates, including fuel load for Unit
3, from those established at the end of the third quarter 2021. The site work plan currently targets fuel load for Unit 3 in the second
quarter 2022 and an in-service date during the third quarter 2022 and primarily depends on significant improvements in overall
construction productivity and production levels, the volume of construction remediation work, the pace of system and area turnovers,
and the progression of startup and other testing. As the site work plan includes minimal margin to these milestone dates, an in-service
date during the fourth quarter 2022 or the first quarter 2023 for Unit 3 is projected, although any further delays could result in a later
in-service date.
As the result of productivity challenges and temporarily diverting some Unit 4 craft and support resources to Unit 3 construction efforts,
at the end of each of the second and third quarters 2021, Southern Nuclear also further extended milestone dates for Unit 4 from those
established in January 2021. The temporary diversion of Unit 4 resources to support Unit 3 has continued into the first quarter 2022;
therefore, at the end of the fourth quarter 2021, Southern Nuclear further extended milestone dates for Unit 4 from those established
at the end of the third quarter 2021. The site work plan targets an in-service date during the first quarter 2023 for Unit 4 and primarily
depends on overall construction productivity and production levels significantly improving as well as appropriate levels of craft laborers,
particularly electricians and pipefitters, being added and maintained. As the site work plan includes minimal margin to the milestone
dates, an in-service date during the third or fourth quarter 2023 for Unit 4 is projected, although any further delays could result in a later
in-service date.
During 2021, established construction contingency and additional costs totaling $1.3 billion were assigned to the base capital cost
forecast for costs primarily associated with schedule extensions, construction productivity, the pace of system turnovers, and support
resources for Units 3 and 4. Georgia Power also increased its total capital cost forecast as of December 31, 2021 by $99 million to replenish
construction contingency.
After considering the significant level of uncertainty that exists regarding the future recoverability of these costs since the ultimate
outcome of these matters is subject to the outcome of future assessments by management, as well as Georgia PSC decisions in future
regulatory proceedings, Georgia Power recorded pre-tax charges to income in the first quarter 2021, the second quarter 2021, the third
quarter 2021, and the fourth quarter 2021 of $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), respectively, for the increases in the total project capital cost forecast.
Georgia Power may request the Georgia PSC to evaluate those expenditures for rate recovery during the prudence review following
the Unit 4 fuel load pursuant to the twenty-fourth VCM stipulation described below. In addition, Georgia Power recorded a pre-tax
charge to income in the fourth quarter 2021 of approximately $440 million ($328 million after tax) for incremental costs, which will
not be recovered from retail customers, associated with the cost-sharing and tender provisions of the joint ownership agreements
described below.
As Unit 3 completes system turnover from construction and moves to testing and transition to operations, ongoing and potential
future challenges include completion of construction remediation work, completion of work packages, including inspection records, and
other documentation necessary to submit the remaining ITAACs and begin fuel load, and final component and pre-operational tests.
As Unit 4 progresses through construction and continues to transition into testing, ongoing and potential future challenges include
the pace and quality of electrical installation, availability of craft and supervisory resources, including the temporary diversion of such
resources to support Unit 3 construction efforts, and the pace of work package closures and system turnovers. As construction, including
subcontract work, continues on both Units 3 and 4, ongoing or future challenges include management of contractors and vendors;
subcontractor performance; supervision of craft labor and related productivity, particularly in the installation of electrical, mechanical,
and instrumentation and controls commodities, ability to attract and retain craft labor, and/or related cost escalation; and procurement
and related installation. New challenges may arise, particularly as Units 3 and 4 move into initial testing and start-up, which may result
in required engineering changes or remediation related to plant systems, structures, or components (some of which are based on new
technology that only within the last few years began initial operation in the global nuclear industry at this scale). The ongoing and
potential future challenges described above may change the projected schedule and estimated cost.
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Southern Company 2021 Annual Report Notes to Financial Statements
There have been technical and procedural challenges to the construction and licensing of Plant Vogtle Units 3 and 4 at the federal and
state level and additional challenges may arise. Processes are in place that are designed to ensure compliance with the requirements
specified in the Westinghouse Design Control Document and the combined construction and operating licenses, including inspections
by Southern Nuclear and the NRC that occur throughout construction. In connection with the additional construction remediation work
described above, Southern Nuclear reviewed the project’s construction quality programs and, where needed, is implementing improvement
plans consistent with these processes. On November 17, 2021, the NRC issued the final significance report on its special inspection to
review the root cause of this additional construction remediation work and the corresponding corrective action plans with two findings
of low to moderate safety significance. Southern Nuclear had already identified and self-reported many of the issues in this report to the
NRC and implemented corrective-action plans to resolve these issues. The NRC will conduct a follow-up inspection on these findings at a
future date. Findings resulting from this or other inspections could require additional remediation and/or further NRC oversight. In addition,
certain license amendment requests have been filed and approved or are pending before the NRC.
The site work plan currently targets fuel load for Units 3 and 4 in the second quarter 2022 and the fourth quarter 2022, respectively.
Various design and other licensing-based compliance matters, including the timely submittal by Southern Nuclear of the ITAAC
documentation for each unit and the related reviews and approvals by the NRC necessary to support NRC authorization to load fuel, have
arisen or may arise, which may result in additional license amendments or require other resolution. If any license amendment requests or
other licensing-based compliance issues, including inspections and ITAACs, are not resolved in a timely manner, there may be delays in the
project schedule that could result in increased costs.
The ultimate outcome of these matters cannot be determined at this time. However, any extension of the in-service date beyond the first
quarter 2023 for Unit 3 or the fourth quarter 2023 for Unit 4, including the current level of cost sharing described below, is estimated
to result in additional base capital costs for Georgia Power of up to $60 million per month for Unit 3 and $40 million per month for Unit
4, as well as the related AFUDC and any additional related construction, support resources, or testing costs. While Georgia Power is not
precluded from seeking retail recovery of any future capital cost forecast increase other than the amounts related to the cost-sharing
and tender provisions of the joint ownership agreements described below, management will ultimately determine whether or not to seek
recovery. Any further changes to the capital cost forecast that are not expected to be recoverable through regulated rates will be required
to be charged to income and such charges could be material.
Joint Owner Contracts
In November 2017, the Vogtle Owners entered into an amendment to their joint ownership agreements for Plant Vogtle Units 3 and 4 to
provide for, among other conditions, additional Vogtle Owner approval requirements. Effective in August 2018, the Vogtle Owners further
amended the joint ownership agreements to clarify and provide procedures for certain provisions of the joint ownership agreements
related to adverse events that require the vote of the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 to
continue construction (as amended, and together with the November 2017 amendment, the Vogtle Joint Ownership Agreements).
The Vogtle Joint Ownership Agreements also confirm that the Vogtle Owners’ sole recourse against Georgia Power or Southern Nuclear
for any action or inaction in connection with their performance as agent for the Vogtle Owners is limited to removal of Georgia Power
and/or Southern Nuclear as agent, except in cases of willful misconduct.
Amendments to the Vogtle Joint Ownership Agreements
In connection with a September 2018 vote by the Vogtle Owners to continue construction, Georgia Power entered into (i) a binding term
sheet (Vogtle Owner Term Sheet) with the other Vogtle Owners and MEAG Power’s wholly-owned subsidiaries MEAG Power SPVJ, LLC
(MEAG SPVJ), MEAG Power SPVM, LLC (MEAG SPVM), and MEAG Power SPVP, LLC (MEAG SPVP) to take certain actions which partially
mitigate potential financial exposure for the other Vogtle Owners, including additional amendments to the Vogtle Joint Ownership
Agreements and the purchase of PTCs from the other Vogtle Owners at pre-established prices, and (ii) a term sheet (MEAG Term Sheet)
with MEAG Power and MEAG SPVJ to provide up to $300 million of funding with respect to MEAG SPVJ’s ownership interest in Plant Vogtle
Units 3 and 4 under certain circumstances. In January 2019, Georgia Power, MEAG Power, and MEAG SPVJ entered into an agreement to
implement the provisions of the MEAG Term Sheet. In February 2019, Georgia Power, the other Vogtle Owners, and MEAG Power’s wholly-
owned subsidiaries MEAG SPVJ, MEAG SPVM, and MEAG SPVP entered into certain amendments to the Vogtle Joint Ownership Agreements
to implement the provisions of the Vogtle Owner Term Sheet (Global Amendments).
Pursuant to the Global Amendments: (i) each Vogtle Owner must pay its proportionate share of qualifying construction costs for Plant
Vogtle Units 3 and 4 based on its ownership percentage up to the estimated cost at completion (EAC) for Plant Vogtle Units 3 and 4 which
formed the basis of Georgia Power’s forecast of $8.4 billion in the nineteenth VCM plus $800 million; (ii) Georgia Power will be responsible
for 55.7% of actual qualifying construction costs between $800 million and $1.6 billion over the EAC in the nineteenth VCM (resulting in
$80 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 44.3% of such costs pro rata
in accordance with their respective ownership interests; and (iii) Georgia Power will be responsible for 65.7% of qualifying construction
102
Southern Company 2021 Annual Report Notes to Financial Statements
costs between $1.6 billion and $2.1 billion over the EAC in the nineteenth VCM (resulting in a further $100 million of potential additional
costs to Georgia Power), with the remaining Vogtle Owners responsible for 34.3% of such costs pro rata in accordance with their respective
ownership interests. If the EAC is revised and exceeds the EAC in the nineteenth VCM by more than $2.1 billion, each of the other Vogtle
Owners will have a one-time option at the time the project budget forecast is so revised to tender a portion of its ownership interest to
Georgia Power in exchange for Georgia Power’s agreement to pay 100% of such Vogtle Owner’s remaining share of total construction costs
in excess of the EAC in the nineteenth VCM plus $2.1 billion.
In addition, pursuant to the Global Amendments, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4
must vote to continue construction if certain adverse events occur, including, among other events: (i) the bankruptcy of Toshiba; (ii) the
termination or rejection in bankruptcy of certain agreements, including the Vogtle Services Agreement, the Bechtel Agreement, or the agency
agreement with Southern Nuclear; (iii) Georgia Power’s public announcement of its intention not to submit for rate recovery any portion of
its investment in Plant Vogtle Units 3 and 4 or the Georgia PSC determines that any of Georgia Power’s costs relating to the construction
of Plant Vogtle Units 3 and 4 will not be recovered in retail rates, excluding any additional amounts paid by Georgia Power on behalf of the
other Vogtle Owners pursuant to the Global Amendments described above and the first 6% of costs during any six-month VCM reporting
period that are disallowed by the Georgia PSC for recovery, or for which Georgia Power elects not to seek cost recovery, through retail rates;
and (iv) an incremental extension of one year or more from the seventeenth VCM report estimated in-service dates of November 2021 and
November 2022 for Units 3 and 4, respectively. The latest schedule extension triggers the requirement that the holders of at least 90% of
the ownership interests in Plant Vogtle Units 3 and 4 must vote to continue construction by March 8, 2022. Georgia Power has voted to
continue construction. In addition, if the holders of at least 90% of the ownership interests of Plant Vogtle Units 3 and 4 do not vote to
continue construction, the DOE may require Georgia Power to prepay all outstanding borrowings under the FFB Credit Facilities over a period
of five years. See Note 8 under “Long-term Debt – DOE Loan Guarantee Borrowings” for additional information.
Georgia Power and the other Vogtle Owners do not agree on either the starting dollar amount for the determination of cost increases
subject to the cost-sharing and tender provisions of the Global Amendments or the extent to which COVID-19-related costs impact the
calculation. Based on the definition in the Global Amendments, Georgia Power believes the starting dollar amount is $18.38 billion and
the current project capital cost forecast has triggered the cost-sharing provisions. The other Vogtle Owners have asserted that the project
cost increases have reached the cost-sharing thresholds and have triggered the tender provisions under the Global Amendments. Georgia
Power recorded an additional pre-tax charge to income in the fourth quarter 2021 of approximately $440 million ($328 million after tax)
associated with these cost-sharing and tender provisions, which is included in the total project capital cost forecast. Georgia Power may
be required to record further pre-tax charges to income of up to approximately $460 million associated with these provisions based on the
current project capital cost forecast. The incremental charges associated with these provisions will not be recovered from retail customers.
On October 29, 2021, Georgia Power and the other Vogtle Owners entered into an agreement to clarify the process for the tender
provisions of the Global Amendments to provide for a decision between 120 and 180 days after the tender option is triggered, which
the other Vogtle Owners assert occurred on February 14, 2022.
Georgia Power’s ownership interest in Plant Vogtle Units 3 and 4 continues to be 45.7%; however, it could increase if one or more of the
other Vogtle Owners exercise the option to tender a portion of their ownership interest to Georgia Power and require Georgia Power to
pay 100% of the remaining share of the costs necessary to complete Plant Vogtle Units 3 and 4. Georgia Power’s incremental ownership
interest would be calculated and conveyed to Georgia Power after Plant Vogtle Units 3 and 4 are placed in service.
The ultimate outcome of these matters cannot be determined at this time.
Regulatory Matters
In 2009, the Georgia PSC voted to certify construction of Plant Vogtle Units 3 and 4 with a certified capital cost of $4.418 billion.
In addition, in 2009 the Georgia PSC approved inclusion of the Plant Vogtle Units 3 and 4 related CWIP accounts in rate base, and the State
of Georgia enacted the Georgia Nuclear Energy Financing Act, which allows Georgia Power to recover financing costs for Plant Vogtle Units
3 and 4. Financing costs are recovered on all applicable certified costs through annual adjustments to the NCCR tariff up to the certified
capital cost of $4.418 billion. At December 31, 2021, Georgia Power had recovered approximately $2.7 billion of financing costs. Financing
costs related to capital costs above $4.418 billion are being recognized through AFUDC and are expected to be recovered through retail
rates over the life of Plant Vogtle Units 3 and 4; however, Georgia Power is not recording AFUDC related to any capital costs in excess of
the total deemed reasonable by the Georgia PSC (currently $7.3 billion) and not requested for rate recovery. On November 18, 2021, the
Georgia PSC approved Georgia Power’s request to decrease the NCCR tariff by $78 million annually, effective January 1, 2022.
Georgia Power is required to file semi-annual VCM reports with the Georgia PSC by February 28 and August 31 of each year. In 2013, in
connection with the eighth VCM report, the Georgia PSC approved a stipulation between Georgia Power and the staff of the Georgia PSC
to waive the requirement to amend the Plant Vogtle Units 3 and 4 certificate in accordance with the 2009 certification order until the
completion of Plant Vogtle Unit 3, or earlier if deemed appropriate by the Georgia PSC and Georgia Power.
103
Southern Company 2021 Annual Report Notes to Financial Statements
In 2016, the Georgia PSC voted to approve a settlement agreement (Vogtle Cost Settlement Agreement) resolving certain prudency
matters in connection with the fifteenth VCM report. In December 2017, the Georgia PSC voted to approve (and issued its related order
on January 11, 2018) Georgia Power’s seventeenth VCM report and modified the Vogtle Cost Settlement Agreement. The Vogtle Cost
Settlement Agreement, as modified by the January 11, 2018 order, resolved the following regulatory matters related to Plant Vogtle
Units 3 and 4: (i) none of the $3.3 billion of costs incurred through December 31, 2015 and reflected in the fourteenth VCM report
should be disallowed from rate base on the basis of imprudence; (ii) the Contractor Settlement Agreement was reasonable and prudent
and none of the $0.3 billion paid pursuant to the Contractor Settlement Agreement should be disallowed from rate base on the basis of
imprudence; (iii) (a) capital costs incurred up to $5.68 billion would be presumed to be reasonable and prudent with the burden of proof
on any party challenging such costs, (b) Georgia Power would have the burden to show that any capital costs above $5.68 billion were
prudent, and (c) a revised capital cost forecast of $7.3 billion (after reflecting the impact of payments received under the Guarantee
Settlement Agreement and related customer refunds) was found reasonable; (iv) construction of Plant Vogtle Units 3 and 4 should be
completed, with Southern Nuclear serving as project manager and Bechtel as primary contractor; (v) approved and deemed reasonable
Georgia Power’s revised schedule placing Plant Vogtle Units 3 and 4 in service in November 2021 and November 2022, respectively;
(vi) confirmed that the revised cost forecast does not represent a cost cap and that a prudence proceeding on cost recovery will occur
following Unit 4 fuel load, consistent with applicable Georgia law; (vii) reduced the ROE used to calculate the NCCR tariff (a) from
10.95% (the ROE rate setting point authorized by the Georgia PSC in the 2013 ARP) to 10.00% effective January 1, 2016, (b) from
10.00% to 8.30%, effective January 1, 2020, and (c) from 8.30% to 5.30%, effective January 1, 2021 (provided that the ROE in no case
will be less than Georgia Power’s average cost of long-term debt); (viii) reduced the ROE used for AFUDC equity for Plant Vogtle Units 3
and 4 from 10.00% to Georgia Power’s average cost of long-term debt, effective January 1, 2018; and (ix) agreed that effective the first
month after Unit 3 reaches commercial operation, retail base rates would be adjusted to include the costs related to Unit 3 and common
facilities deemed prudent in the Vogtle Cost Settlement Agreement (see “Plant Vogtle Unit 3 and Common Facilities Rate Proceeding”
herein for additional information). The January 11, 2018 order also stated that if Plant Vogtle Units 3 and 4 are not commercially
operational by June 1, 2021 and June 1, 2022, respectively, the ROE used to calculate the NCCR tariff will be further reduced by 10
basis points each month (but not lower than Georgia Power’s average cost of long-term debt) until the respective Unit is commercially
operational. The ROE reductions negatively impacted earnings by approximately $270 million, $150 million, and $75 million in 2021,
2020, and 2019, respectively, and are estimated to have negative earnings impacts of approximately $300 million and $265 million
in 2022 and 2023, respectively. In its January 11, 2018 order, the Georgia PSC also stated if other conditions change and assumptions
upon which Georgia Power’s seventeenth VCM report are based do not materialize, the Georgia PSC reserved the right to reconsider the
decision to continue construction.
The Georgia PSC has approved 24 VCM reports covering periods through December 31, 2020, including total construction capital costs
incurred through December 31, 2020 of $7.3 billion (net of $1.7 billion of payments received under the Guarantee Settlement Agreement
and approximately $188 million in related customer refunds). In the August 24, 2021 order approving the twenty-fourth VCM report, the
Georgia PSC also approved a stipulation addressing the following matters: (i) beginning with its twenty-fifth VCM report, Georgia Power
will continue to report to the Georgia PSC all costs incurred during the period for review and will request for approval costs up to the
$7.3 billion determined to be reasonable in the Georgia PSC’s seventeenth VCM order and (ii) Georgia Power will not seek rate recovery of
the $0.7 billion increase to the base capital cost forecast included in the nineteenth VCM report and charged to income by Georgia Power
in the second quarter 2018. In addition, the stipulation confirms Georgia Power may request verification and approval of costs above
$7.3 billion for inclusion in rate base at a later time, but no earlier than the prudence review contemplated by the seventeenth VCM order
described previously. The Georgia PSC is scheduled to vote on the twenty-fifth VCM report on February 17, 2022. Georgia Power also
expects to file its twenty-sixth VCM report with the Georgia PSC on February 17, 2022, which will reflect the revised capital cost forecast
described above.
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.
104
Southern Company 2021 Annual Report Notes to Financial Statements
2019 Base Rate Case
In March 2020, the Mississippi PSC approved a settlement agreement between Mississippi Power and the Mississippi Public Utilities Staff
related to Mississippi Power’s base rate case filed in 2019 (Mississippi Power Rate Case Settlement Agreement).
Under the terms of the Mississippi Power Rate Case Settlement Agreement, annual retail rates decreased approximately $16.7 million, or
1.85%, effective for the first billing cycle of April 2020, based on a test year period of January 1, 2020 through December 31, 2020, a 53%
average equity ratio, an allowed maximum actual equity ratio of 55% by the end of 2020, and a 7.57% return on investment.
Additionally, the Mississippi Power Rate Case Settlement Agreement: (i) established common amortization periods of four years for
regulatory assets and three years for regulatory liabilities included in the approved revenue requirement, including those related to
unprotected deferred income taxes; (ii) established new depreciation rates reflecting an annual increase in depreciation of approximately
$10 million; and (iii) excluded certain compensation costs totaling approximately $3.9 million. It also eliminated separate rates for
costs associated with Plant Ratcliffe and energy efficiency initiatives and includes such costs in the PEP, ECO Plan, and ad valorem tax
adjustment factor, as applicable.
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
and the PEP lookback filing. In July 2020, the Mississippi PSC approved Mississippi Power’s revisions to the PEP compliance rate clause as
agreed to in the Mississippi Power Rate Case Settlement Agreement. These revisions include, among other things, changing the filing date
for the annual PEP rate projected filing from November of the immediately preceding year to March of the current year, utilizing a historic
test year adjusted for “known and measurable” changes, using discounted cash flow and regression formulas to determine base ROE, and
moving all embedded ad valorem property taxes currently collected in PEP to the ad valorem tax adjustment clause. The PEP lookback
filing will continue to be filed after the end of the year and allows for review of the actual revenue requirement.
Pursuant to a Mississippi PSC-approved settlement agreement between Mississippi Power and the MPUS, Mississippi Power was not
required to make any PEP filings for regulatory years 2019 and 2020. On June 8, 2021, the Mississippi PSC approved Mississippi Power’s
annual retail PEP filing for 2021, resulting in an annual increase in revenues of approximately $16 million, or 1.8%, which became effective
with the first billing cycle of April 2021.
Integrated Resource Plan
In 2019, Mississippi Power updated its proposed Reserve Margin Plan (RMP), originally filed in 2018, as required by the Mississippi PSC. In
2018, Mississippi Power had proposed alternatives to reduce its reserve margin and lower or avoid operating costs. In December 2020, the
Mississippi PSC issued an order concluding the RMP docket and 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 Mississippi Power’s excess reserve margin.
The order stated that Mississippi Power will be allowed to defer any retirement-related costs as regulatory assets for future recovery.
On September 9, 2021, the Mississippi PSC issued an order confirming the conclusion of its review of Mississippi Power’s 2021 IRP with no
deficiencies identified. 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 reflects 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.
The remaining net book value of Plant Daniel Units 1 and 2 was approximately $515 million at December 31, 2021 and Mississippi Power
is continuing to depreciate these units using the current approved rates through the end of 2027. Mississippi Power expects to reclassify
the net book value remaining at retirement, which is expected to total approximately $386 million, to a regulatory asset to be amortized
over a period to be determined by the Mississippi PSC in future proceedings, consistent with the December 2020 order. The Plant Watson
and Greene County units are expected to be fully depreciated upon retirement. The ultimate outcome of these matters cannot be
determined at this time. See Note 3 under “Other Matters – Mississippi Power” for additional information on Plant Daniel Units 1 and 2.
105
Southern Company 2021 Annual Report Notes to Financial Statements
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 accordance with a Mississippi PSC-approved settlement agreement between Mississippi Power and the MPUS, Mississippi Power was not
required to make any ECO Plan filings for 2019 and 2020, and any necessary adjustments were reflected in Mississippi Power’s 2019 base
rate case.
In 2019, the Mississippi PSC approved Mississippi Power’s request for a CPCN to complete certain environmental compliance projects,
primarily associated with the Plant Daniel coal units co-owned 50% with Gulf Power. The total estimated cost is approximately
$125 million, with Mississippi Power’s share of approximately $67 million being proposed for recovery through its ECO Plan. As of
December 31, 2021, approximately $20 million of Mississippi Power’s share is included in plant in service, approximately $14 million
is included in CWIP, and approximately $13 million associated with ash pond closure is reflected in Mississippi Power’s ARO liabilities.
See Note 6 for additional information on AROs and Note 3 under “Other Matters – Mississippi Power” for additional information on Gulf
Power’s ownership in Plant Daniel.
On June 8, 2021, the Mississippi PSC approved Mississippi Power’s ECO Plan filing for 2021, resulting in a decrease in revenues of
approximately $9 million annually, primarily due to a change in the amortization periods of certain regulatory assets and liabilities.
The rate decrease became effective with the first billing cycle of July 2021.
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 decreases of $35 million and $24 million effective in February 2019 and 2020,
respectively, and increases of $2 million and $43 million effective in February 2021 and 2022, respectively. At December 31, 2021,
under recovered retail fuel costs totaled approximately $4 million and were included in other customer accounts receivable on Southern
Company’s and Mississippi Power’s balance sheets. At December 31, 2020, over recovered retail fuel costs totaled $24 million and were
included in other current liabilities on Southern Company’s balance sheet and over recovered regulatory clause liabilities on Mississippi
Power’s balance sheet.
Mississippi Power has wholesale MRA and Market Based (MB) fuel cost recovery factors. Effective with the first billing cycles for January
2020, 2021, and 2022, annual revenues under the wholesale MRA fuel rate increased $1 million, decreased $5 million, and increased
$11 million, respectively. The wholesale MB fuel rate did not change materially in any period presented. At December 31, 2021, under
recovered wholesale fuel costs were immaterial. At December 31, 2020, over recovered wholesale fuel costs totaled approximately
$10 million and were included in other current liabilities on Southern Company’s balance sheet and over recovered regulatory clause
liabilities on Mississippi Power’s balance sheet.
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 establishes annually an ad valorem tax adjustment factor that is approved by the Mississippi PSC to collect the ad
valorem taxes paid by Mississippi Power. In 2020 and 2019, the annual revenues collected through the ad valorem tax adjustment factor
increased by $10 million and decreased by $2 million, respectively. On April 6, 2021, the Mississippi PSC approved Mississippi Power’s
annual ad valorem tax adjustment filing for 2021, which requested an annual increase in revenues of approximately $28 million, including
approximately $19 million of ad valorem taxes previously recovered through PEP in accordance with the Mississippi Power Rate Case
Settlement Agreement. The rate increase became effective with the first billing cycle of May 2021.
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).
106
Southern Company 2021 Annual Report Notes to Financial Statements
Mississippi Power’s net retail SRR accrual, which includes carrying costs and amortization of related excess deferred income tax benefits,
was $(1.8) million in 2021, $0.8 million 2020, and $1.4 million in 2019. At December 31, 2020, the retail property damage reserve balance
was $4 million. On October 14, 2021, the Mississippi PSC issued an accounting order giving Mississippi Power the authority to reclassify
the retail costs associated with Hurricanes Zeta and Ida (approximately $49 million) to a regulatory asset to be recovered through PEP over
a period to be determined in Mississippi Power’s 2022 PEP proceeding. At December 31, 2021, the retail property damage reserve balance
was $31 million, which reflects the impact of the reclassification.
On December 7, 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. The Mississippi PSC also established $8 million
as the minimum annual accrual amount until a target property damage reserve balance of $75 million is met. 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.
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. The SSA may be cancelled by Cooperative Energy with 10 years notice. Cooperative Energy has the option to decrease its use of
Mississippi Power’s generation services under the MRA tariff up to 2.5% annually, with required notice, with a remaining total reduction of
8%, or approximately $8 million in cumulative annual base revenues.
In June 2020, the FERC accepted Mississippi Power’s requested $2 million annual increase in MRA base rates effective June 1, 2020, as
agreed upon in a settlement agreement reached with its wholesale customers.
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.
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
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.
107
Southern Company 2021 Annual Report Notes to Financial Statements
The following table provides regulatory information for Southern Company Gas’ natural gas distribution utilities:
Authorized ROE(a)
Weather normalization mechanisms(b)
Decoupled, including straight-fixed-variable rates(c)
Regulatory infrastructure program rates(d)
Bad debt rider(e)
Energy efficiency plan(f)
Notes to Financial Statements
Annual base rate adjustment mechanism(g)
Year of last base rate case decision(h)
Goodwill and Other Intangible Assets and Liabilities
Nicor Gas
Atlanta Gas Light
Virginia Natural Gas
Chattanooga Gas
9.75 %
10.25%
9.50 %
9.80%
2021
2019
2021
2018
Southern Power’s intangible assets consist primarily of certain PPAs acquired, which are amortized over the term of the respective PPA.
(a) Represents the authorized ROE at December 31, 2021.
(b) 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
Southern Company Gas’ goodwill and other intangible assets and liabilities primarily relate to its 2016 acquisition by Southern Company.
impacts on earnings of weather and customer consumption.
In addition to these items, Southern Company’s goodwill and other intangible assets also relate to its 2016 acquisition of PowerSecure.
(c) 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.
Goodwill is not amortized, but is subject to an annual impairment test during the fourth quarter of each year, or more frequently if
(d) Programs that update or expand distribution systems and LNG facilities. Atlanta Gas Light’s infrastructure program, System Reinforcement Rider, is effective
impairment indicators arise. Southern Company and Southern Company Gas each evaluated its goodwill in the fourth quarter 2021 and
for 2022 through 2024. See “Rate Proceedings – Atlanta Gas Light” herein for additional information. Chattanooga Gas’ pipeline replacement program costs
determined no impairment was required. See Note 15 under “Southern Company” for information regarding impairments to goodwill and
are recovered through its annual base rate review mechanism.
(e) The recovery (refund) of bad debt expense over (under) an established benchmark expense. The gas portion of bad debt expense is recovered through
other intangible assets recorded in 2019.
purchased gas adjustment mechanisms. Nicor Gas also has a rider to recover the non-gas portion of bad debt expense.
At December 31, 2021 and 2020, goodwill was as follows:
(f) Recovery of costs associated with plans to achieve specified energy savings goals.
(g) Regulatory mechanism allowing annual adjustments to base rates up or down based on authorized ROE and/or ROE range.
(h) Annual GRAM filing required at Atlanta Gas Light.
Southern Company
Southern Company Gas:
Infrastructure Replacement Programs and Capital Projects
Goodwill
(in millions)
$5,280
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.
Gas distribution operations
Gas marketing services
Southern Company Gas total
$4,034
981
$5,015
Total capital expenditures incurred during 2021 for gas distribution operations were $1.5 billion.
At December 31, 2021 and 2020, other intangible assets were as follows:
The following table and discussions provide updates on the infrastructure replacement programs and capital projects at the natural gas
distribution utilities at December 31, 2021. These programs are risk-based and designed to update and replace cast iron, bare steel, and
At December 31, 2021
At December 31, 2020
mid-vintage plastic materials or expand Southern Company Gas’ distribution systems to improve reliability and meet operational flexibility
and growth.
Southern Company
Other intangible assets subject
Utility
Program
to amortization:
Customer relationships
Trade names
Storage and transportation contracts(*)
Investing in Illinois(*)
PPA fair value adjustments
Virginia Natural Gas
Other
Steps to Advance
Virginia’s Energy (SAVE)
Nicor Gas
Total other intangible assets subject
System Reinforcement
Rider
Atlanta Gas Light
to amortization
Recovery
Rider
Rider
Rider
Other intangible assets not subject
Chattanooga Gas
Pipeline Replacement
Program
to amortization:
Federal Communications Commission licenses
Total
Rate Base
Total other intangible assets
Gross
Carrying
Amount
Accumulated
Amortization
(in millions)
Other
Intangible
Assets, Net
Gross
Carrying
Amount
Accumulated
Amortization
(in millions)
Other
Intangible
Assets, Net
Expenditures
in 2021
Expenditures
Since Project
Inception
$ 212
64
—
390
11
(in millions)
$ (150)
(38)
—
(109)
(10)
$2,508
$ 677
$ (307)
$408
51
—
2
342
—
2
Pipe
Installed
Since
Project
Inception
$ 62
(miles)
26
1,153
—
281
1
470
Scope of
Program
$212
64
64
390
10
(miles)
1,394
640
Program
Duration
$(135)
(years)
(31)
9
(64)
(89)
13
(9)
Last
Year of
Program
2023
$ 77
33
—
301
1
2024
$370
N/A
$740
N/A
3
$(328)
2024
$412
5
73
7
2027
$461
75
$ 752
$2,852
—
$ (307)
75
1,628
$445
2,107
75
$815
—
$(328)
75
$487
(*) Includes replacement of pipes, compressors, and transmission mains along with other improvements such as new meters. Scope of program miles is an
Southern Power
estimate and subject to change. Recovery of program costs is described under “Nicor Gas” herein.
Other intangible assets subject
to amortization:
PPA fair value adjustments
Southern Company Gas
Other intangible assets subject
to amortization:
Gas marketing services
108 Southern Company 2021 Annual Report
Customer relationships
Trade names
Wholesale gas services
Storage and transportation contracts(*)
Total other intangible assets subject
$ 390
$ (109)
$281
$390
$ (89)
$301
$ 156
26
—
$ (130)
(15)
$ 26
11
$156
26
$(119)
(12)
—
—
64
(64)
$ 37
14
—
to amortization
$ 182
$ (145)
$ 37
$246
$(195)
$ 51
(*) See Note 15 under “Southern Company Gas” for information regarding the sale of Sequent.
Southern Company 2021 Annual Report
85
Notes to Financial Statements
Nicor Gas
Illinois legislation allows Nicor Gas to provide more widespread safety and reliability enhancements to its distribution system 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, subject to annual review. In accordance with orders from the Illinois Commission, Nicor Gas recovers program costs
incurred through a separate rider and base rates. The Illinois Commission’s approval of Nicor Gas’ rate case on November 18, 2021 included
recovery of program costs through December 31, 2021. See “Rate Proceedings – Nicor Gas” herein for additional information. Nicor Gas’
capital expenditures related to qualifying projects under the Investing in Illinois program totaled $389 million and $396 million in 2020 and
2019, respectively.
Virginia Natural Gas
In 2019, the Virginia Commission approved amendments to and extension of the Steps to Advance Virginia’s Energy (SAVE) program,
an accelerated infrastructure replacement program. The extension allows Virginia Natural Gas to continue replacing aging pipeline
infrastructure through 2024 and increases its authorized investment under the previously-approved plan from $35 million to $40 million
in 2019 with additional annual investments of $50 million in 2020, $60 million in 2021, $70 million in each year from 2022 through 2024,
and 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. Virginia Natural Gas’ capital expenditures under the SAVE program totaled $49 million and $45 million in
2020 and 2019, respectively.
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 2021, Virginia Natural Gas is recovering program costs incurred prior to November 1, 2020 through base rates. Program
costs incurred subsequent to November 1, 2020 are currently being recovered through a separate rider and are subject to future base rate
case proceedings.
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 recognized in 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 the related under recovered amount or December 31, 2025. The under recovered balance at December
31, 2021 was $91 million, including $47 million of unrecognized equity return. 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 November 18, 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.
Chattanooga Gas
In June 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.
109
Southern Company 2021 Annual Report Notes to Financial Statements
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.
Changes in the billing factor will not have a significant effect on Southern Company’s or Southern Company Gas’ net income, but will
affect 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, 2021, the under recovered balance
was $473 million, $266 million of which was included in natural gas cost under recovery and $207 million of which was included in
other regulatory assets, deferred on Southern Company’s and Southern Company Gas’ balance sheets. At December 31, 2020, the over
recovered balance was $88 million, which was included in other regulatory liabilities on Southern Company’s and Southern Company Gas’
balance sheets.
Rate Proceedings
Nicor Gas
In 2019, the Illinois Commission approved a $168 million annual base rate increase effective October 8, 2019. The base rate increase
included $65 million related to the recovery of program costs under the Investing in Illinois program and was based on a ROE of 9.73% and
an equity ratio of 54.2%. Additionally, the Illinois Commission approved a volume balancing adjustment, a revenue decoupling mechanism
for residential customers that provides a benchmark level of revenue per rate class for recovery.
On November 18, 2021, the Illinois Commission approved a $240 million annual base rate increase 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%.
Atlanta Gas Light
In 2019, the Georgia PSC approved a $65 million annual base rate increase, effective January 1, 2020, based on a ROE of 10.25% and
an equity ratio of 56%. Earnings will be evaluated 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 approved continuation of the previously authorized inclusion
in base rates of the recovery of and return on the infrastructure program investments, including, but not limited to, GRAM adjustments,
and a reauthorization and continuation of GRAM until terminated by the Georgia PSC. GRAM filing rate adjustments will be based on
the 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 July 2020, Atlanta Gas Light filed its annual GRAM filing with the Georgia PSC requesting an annual base rate increase of $37.6 million
based on the projected 12-month period beginning January 1, 2021, which did not exceed the 5% limitation established by the Georgia
PSC. Rates went into effect on January 1, 2021 in accordance with Atlanta Gas Light’s 2019 rate case order.
On February 16, 2021, the Georgia PSC approved a stipulation between Atlanta Gas Light and the Georgia PSC staff establishing a long-
range comprehensive planning process. Under the terms of the stipulation, Atlanta Gas Light was required to develop and file at least
triennially an Integrated Capacity and Delivery Plan (i-CDP). Each i-CDP will include a 10-year forecast of interstate and intrastate capacity
asset requirements, including a detailed plan for the first three years consistent with Atlanta Gas Light’s current capacity supply plan, and a
10-year projection of capital budgets and related operations and maintenance spending. Recovery of the related revenue requirements will
be included in either subsequent annual GRAM filings or a new System Reinforcement Rider for authorized large pressure improvement and
system reliability projects.
On April 28, 2021, Atlanta Gas Light filed its first i-CDP with the Georgia PSC, which includes 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.
On November 18, 2021, the Georgia PSC approved an October 14, 2021 joint 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, or $5 million for 2022. The stipulation
agreement also provides for $1.7 billion of total capital investment for the years 2022 through 2024.
110
Southern Company 2021 Annual Report Notes to Financial Statements
Also on November 18, 2021, the Georgia PSC approved Atlanta Gas Light’s amended annual GRAM filing, which resulted in an annual rate
increase of $43 million effective January 1, 2022.
Virginia Natural Gas
On September 14, 2021, the Virginia Commission approved a stipulation agreement related to Virginia Natural Gas’ June 2020 general
rate case filing, which allows 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 rate adjustments became effective
as of November 1, 2020, subject to refund, based on Virginia Natural Gas’ original request for an increase of approximately $50 million.
Refunds to customers related to the difference between the approved rates and the interim rates were completed during the fourth
quarter 2021.
Deferral of Incremental COVID-19 Costs
As discussed under “Utility Regulation and Rate Design,” the natural gas distribution utilities have various regulatory mechanisms to
recover bad debt expense, which helped mitigate potential increases in bad debt expense as a result of the COVID-19 pandemic. Deferred
incremental costs related to the COVID-19 pandemic were immaterial for Virginia Natural Gas.
Atlanta Gas Light
In April 2020, in response to the COVID-19 pandemic, the Georgia PSC approved orders directing Atlanta Gas Light to continue its
previous, voluntary suspension of customer disconnections. In June 2020, the Georgia PSC ordered Atlanta Gas Light to resume customer
disconnections beginning July 2020, with exceptions for customers still covered by a shelter-in-place order. All suspensions for customer
disconnections were lifted in October 2020. The orders provide the Marketers, including SouthStar, with a mechanism to receive credits
from Atlanta Gas Light for the base rates it charged to the Marketers of non-paying customers during the suspension. Atlanta Gas Light
will begin recovering these credits through GRAM rates effective January 1, 2023.
Nicor Gas
In March 2020, in response to the COVID-19 pandemic, the Illinois Commission issued an order directing utilities to cease disconnections for
non-payment and to suspend the imposition of late payment fees or penalties. In June 2020, the Illinois Commission approved a stipulation
pursuant to which Nicor Gas and other utilities in Illinois would provide more flexible credit and collection procedures to assist customers with
financial hardship and which authorizes a special purpose rider for recovery of the following COVID-19 pandemic-related impacts: incremental
costs directly associated with the COVID-19 pandemic, net of the offset for COVID-19 pandemic-related credits received, foregone late fees,
foregone reconnection charges, and the costs associated with a bill payment assistance program. Nicor Gas resumed late payment fees in
July 2020 and, on October 1, 2020, began recovery of the COVID-19 pandemic-related impacts through the special purpose rider, which will
continue over a 24-month period. On March 18, 2021, the Illinois Commission approved a phased-in schedule for disconnections related to
non-payment. Nicor Gas began certain disconnections in late April 2021 and resumed normal disconnections in June 2021. At December 31,
2021 and 2020, Nicor Gas’ related regulatory asset was $5 million and $9 million, respectively.
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 composed 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.
December 31, 2021
December 31, 2020
(in millions)
Atlanta Gas Light
Virginia Natural Gas
Chattanooga Gas
Nicor Gas
Total
$47
10
4
—
$61
$59
10
2
3
$74
111
Southern Company 2021 Annual Report Notes to Financial Statements
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 believe the pending legal challenges discussed below have no merit; however, the ultimate outcome of these matters
cannot be determined at this time.
Southern Company
In February 2017, Jean Vineyard and Judy Mesirov each filed a shareholder derivative lawsuit in the U.S. District Court for the Northern
District of Georgia. Each of these lawsuits names as defendants Southern Company, certain of its directors, certain of its current and
former officers, and certain former Mississippi Power officers. In 2017, these two shareholder derivative lawsuits were consolidated in
the U.S. District Court for the Northern District of Georgia. The complaints allege that the defendants caused Southern Company to make
false or misleading statements regarding the Kemper County energy facility cost and schedule. Further, the complaints allege that the
defendants were unjustly enriched and caused the waste of corporate assets and also allege that the individual defendants violated their
fiduciary duties.
In May 2017, Helen E. Piper Survivor’s Trust filed a shareholder derivative lawsuit in the Superior Court of Gwinnett County, Georgia that
names as defendants Southern Company, certain of its directors, certain of its current and former officers, and certain former Mississippi
Power officers. The complaint alleges that the individual defendants, among other things, breached their fiduciary duties in connection
with schedule delays and cost overruns associated with the construction of the Kemper County energy facility. The complaint further
alleges that the individual defendants authorized or failed to correct false and misleading statements regarding the Kemper County energy
facility schedule and cost and failed to implement necessary internal controls to prevent harm to Southern Company. In August 2019, the
court granted a motion filed by the plaintiff in July 2019 to substitute a new named plaintiff, Martin J. Kobuck, in place of Helen E. Piper
Survivor’s Trust.
The plaintiffs in each of these cases seek to recover, on behalf of Southern Company, unspecified actual damages and, on each plaintiff’s
own behalf, attorneys’ fees and costs in bringing the lawsuit. The plaintiffs also seek certain changes to Southern Company’s corporate
governance and internal processes. On January 21, 2022, the plaintiffs in the federal court action filed a motion for preliminary approval
of settlement, together with an executed stipulation of settlement, which applies to both the federal and state actions. The terms of the
settlement are not expected to have a material impact on Southern Company’s financial statements.
Georgia Power
In 2011, plaintiffs filed a putative class action against Georgia Power in the Superior Court of Fulton County, Georgia alleging that Georgia
Power’s collection in rates of amounts for municipal franchise fees (which fees are paid to municipalities) exceeded the amounts allowed in
orders of the Georgia PSC and alleging certain state law claims. This case has been ruled upon and appealed numerous times over the last
several years. In October 2019, the Georgia PSC issued an order that found Georgia Power has appropriately implemented the municipal
franchise fee schedule. On March 16, 2021, the Superior Court of Fulton County granted class certification and Georgia Power’s motion for
summary judgment. On March 22, 2021, the plaintiffs filed a notice of appeal, and, on April 2, 2021, Georgia Power filed a notice of cross
appeal on the issue of class certification. On December 1, 2021, the Georgia Court of Appeals affirmed the Superior Court’s ruling that
granted summary judgment to Georgia Power and dismissed Georgia Power’s cross appeal on the issue of class certification as moot. On
December 21, 2021, the plaintiffs filed a petition for writ of certiorari to the Georgia Supreme Court. The amount of any possible losses
cannot be estimated at this time because, among other factors, it is unknown whether any losses would be subject to recovery from any
municipalities.
112
Southern Company 2021 Annual Report Notes to Financial Statements
In July 2020, a group of individual plaintiffs filed a complaint in the Superior Court of Fulton County, Georgia against Georgia Power
alleging that releases from Plant Scherer have impacted groundwater, surface water, and air, resulting in alleged personal injuries and
property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages, a medical monitoring
fund, and injunctive relief. Georgia Power has filed multiple motions to dismiss the complaint. On October 8, 2021, three additional
complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power alleging that releases from Plant Scherer
have impacted groundwater and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount
of monetary damages including punitive damages. On November 11, 2021, Georgia Power filed a notice to remove the three cases pending
in the Superior Court of Monroe County to the U.S. District Court in the Middle District of Georgia. On February 7, 2022, four additional
complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power seeking damages for alleged personal injuries
or property damage. The amount of any possible losses from these matters cannot be estimated at this time.
Mississippi Power
In 2018, Ray C. Turnage and 10 other individual plaintiffs filed a putative class action complaint against Mississippi Power and the three
then-serving members of the Mississippi PSC in the U.S. District Court for the Southern District of Mississippi, which was amended in March
2019 to include four additional plaintiffs. Mississippi Power received Mississippi PSC approval in 2013 to charge a mirror CWIP rate premised
upon including in its rate base pre-construction and construction costs for the Kemper IGCC prior to placing the Kemper IGCC into service.
The Mississippi Supreme Court reversed that approval and ordered Mississippi Power to refund the amounts paid by customers under the
previously-approved mirror CWIP rate. The plaintiffs allege that the initial approval process, and the amount approved, were improper and
make claims for gross negligence, reckless conduct, and intentional wrongdoing. They also allege that Mississippi Power underpaid customers
by up to $23.5 million in the refund process by applying an incorrect interest rate. The plaintiffs seek to recover, on behalf of themselves and
their putative class, actual damages, punitive damages, pre-judgment interest, post-judgment interest, attorney’s fees, and costs. The district
court dismissed the amended complaint; however, in March 2020, the plaintiffs filed a motion seeking to name the new members of the
Mississippi PSC, the Mississippi Development Authority, and Southern Company as additional defendants and add a cause of action against
all defendants based on a dormant commerce clause theory under the U.S. Constitution. In July 2020, the plaintiffs filed a motion for leave
to file a third amended complaint, which included the same federal claims as the proposed second amended complaint, as well as several
additional state law claims based on the allegation that Mississippi Power failed to disclose the annual percentage rate of interest applicable
to refunds. In November 2020, the court denied each of the plaintiffs’ pending motions and entered final judgment in favor of Mississippi
Power. On January 22, 2021, the court denied further motions by the plaintiffs to vacate the judgment and to file a revised second amended
complaint. On February 19, 2021, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit. An adverse
outcome in this proceeding could have a material impact on Mississippi Power’s financial statements.
Environmental Remediation
The Southern Company system must comply with environmental laws and regulations governing the handling and disposal of waste and
releases of hazardous substances. Under these various laws and regulations, the Southern Company system could incur substantial costs to
clean up affected sites. The traditional electric operating companies and the natural gas distribution utilities 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 2021, 2020, and 2019, Georgia Power recovered approximately $12 million, $12 million,
and $2 million, respectively, through the ECCR tariff for environmental remediation.
Southern Company Gas is subject to environmental remediation liabilities associated with 40 former MGP sites in four different states.
Southern Company Gas’ accrued environmental remediation liability at December 31, 2021 and 2020 was based on the estimated cost of
environmental investigation and remediation associated with these sites.
113
Southern Company 2021 Annual Report Notes to Financial Statements
At December 31, 2021 and 2020, 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.
At December 31, 2021 and 2020, Alabama Power did not have environmental remediation liabilities and Mississippi Power’s balance
was immaterial.
December 31, 2021:
Environmental remediation liability:
Other current liabilities
Accrued environmental remediation
Under recovered environmental remediation costs:
Other regulatory assets, current
Other regulatory assets, deferred
December 31, 2020:
Environmental remediation liability:
Other current liabilities
Accrued environmental remediation
Under recovered environmental remediation costs:
Other regulatory assets, current
Other regulatory assets, deferred
Southern
Company
Georgia
Power
Southern
Company Gas
(in millions)
$ 69
197
$ 71
231
$ 44
216
$ 46
265
$17
—
$12
23
$15
—
$12
29
$ 52
197
$ 59
208
$ 29
216
$ 34
236
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 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 the 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 lawsuits against the U.S. government 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 additional lawsuits against the U.S. government in the Court of Federal Claims 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 August 2020, Alabama Power and Georgia Power filed amended complaints in each of the lawsuits adding
damages 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 $110 million and $132 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, 2021 for any potential
recoveries from the pending lawsuits.
114
Southern Company 2021 Annual Report Notes to Financial Statements
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 $13.5 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 $138 million per incident for each licensed reactor it operates but not more than an
aggregate of $20 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
$275 million and $267 million, respectively, per incident, but not more than an aggregate of $41 million and $40 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, 2023. 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.
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 Units 3 and 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, 2021 under the NEIL policies would
be $52 million and $83 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.
115
Southern Company 2021 Annual Report Notes to Financial Statements
Other Matters
Mississippi Power
Kemper County Energy Facility
In 2019, 2020, and 2021, 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 $24 million pre-tax and after tax in 2019, $4 million pre-tax ($3 million after tax) in 2020, and
$11 million pre-tax ($8 million after tax) in 2021. 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 $10 million to $20 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.
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 September 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. The expected impact of the
closeout agreement was accrued in 2019. In connection with the DOE closeout discussions, in 2019, the Civil Division of the Department
of Justice informed Southern Company and Mississippi Power of an investigation related to the grants received. The ultimate outcome of
this matter cannot be determined at this time; however, it could have a material impact on Southern Company’s and Mississippi Power’s
financial statements.
Plant Daniel
In conjunction with Southern Company’s sale of Gulf Power, NextEra Energy held back $75 million of the purchase price pending Mississippi
Power and Gulf Power negotiating a mutually acceptable revised operating agreement for Plant Daniel. In addition, Mississippi Power and
Gulf Power agreed to seek a restructuring of their 50% undivided ownership interests in the Plant Daniel coal units such that each of them
would, after the restructuring, own 100% of a generating unit. In 2019, Gulf Power provided notice to Mississippi Power that Gulf Power
will retire its share of the coal generating capacity of Plant Daniel on January 15, 2024. Mississippi Power has the option to purchase Gulf
Power’s ownership interest for $1 on January 15, 2024, provided that Mississippi Power exercises the option no later than 120 days prior
to that date. Mississippi Power is assessing the potential operational and economic effects of Gulf Power’s notice. Mississippi Power and
Gulf Power are continuing negotiations on a mutually acceptable revised operating agreement. The impacts of operating the units on an
individual basis continue to be evaluated by Mississippi Power and any transfer of ownership would be subject to approval by the FERC
and the Mississippi PSC. The ultimate outcome of this matter cannot be determined at this time. See Note 2 under “Mississippi Power –
Integrated Resource Plan” for additional information on Plant Daniel and Note 15 under “Southern Company” for information regarding the
sale of Gulf Power.
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.
116
Southern Company 2021 Annual Report Notes to Financial Statements
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 $6 million, $5 million, and $6 million in 2021, 2020, and 2019, respectively. At December 31, 2021, Georgia Power’s estimated long-
term obligations related to this commitment totaled $42 million, consisting of $4 million for 2022, $3 million annually for 2023 through
2025, $1 million for 2026, and $28 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 56 million mmBtu at floating gas prices calculated
using forward natural gas prices at December 31, 2021 and valued at $222 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, 2021
were as follows:
2022
2023
2024
2025
2026
Thereafter
Total
Guarantees
Pipeline Charges, Storage
Capacity, and Gas Supply
(in millions)
$ 634
455
376
275
164
910
$2,814
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.
Alabama Power has guaranteed a $100 million principal amount long-term bank loan SEGCO entered into in 2018 and subsequently
extended in 2021. 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, 2021, the capitalization of SEGCO consisted of $82 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. In addition, SEGCO had short-term debt
outstanding of $20 million. 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.
117
Southern Company 2021 Annual Report Notes to Financial Statements
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:
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 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
118
Southern Company 2021 Annual Report Notes to Financial Statements
2020
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)
$ 6,113
4,699
2,775
90
13,677
$2,377
1,512
1,293
21
5,203
$3,476
2,933
1,197
60
7,666
$ 260
254
285
9
808
1,338
340
971
30
209
2,888
735
454
210
1,399
1,727
391
33
2,151
982
—
—
—
—
—
—
133
108
43
284
—
—
—
—
159
—
—
—
—
—
—
42
50
10
102
—
—
—
—
447
—
—
—
—
—
—
9
3
311
323
—
—
—
—
26
21,097
3,764
(4,486)
$20,375
5,646
184
—
$5,830
8,215
94
—
$8,309
1,157
15
—
$1,172
$ —
—
—
—
—
—
—
—
—
—
—
570
296
239
1,105
—
—
—
—
14
1,119
614
—
$ 1,733
$ —
—
—
—
—
1,338
340
971
30
209
2,888
—
—
—
—
1,727
391
33
2,151
—
5,039
2,881
(4,486)
$ 3,434
119
Southern Company 2021 Annual Report Notes to Financial Statements
2019
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 pipeline investments
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)
$ 6,164
5,065
3,126
90
14,445
$2,509
1,677
1,460
25
5,671
$3,377
3,097
1,360
54
7,888
$ 278
291
306
11
886
1,413
389
907
35
245
2,989
833
453
232
1,518
32
2,095
440
42
2,609
1,035
—
—
—
—
—
—
145
102
81
328
—
—
—
—
—
153
—
—
—
—
—
—
60
54
9
123
—
—
—
—
—
407
—
—
—
—
—
—
11
3
352
366
—
—
—
—
—
19
22,596
4,266
(5,443)
$21,419
6,152
(27)
—
$6,125
8,418
(10)
—
$8,408
1,271
(7)
—
$1,264
$ —
—
—
—
—
—
—
—
—
—
—
648
322
238
1,208
—
—
—
—
—
12
1,220
718
—
$1,938
$ —
—
—
—
—
1,413
389
907
35
245
2,989
—
—
—
—
32
2,095
440
42
2,609
—
5,598
3,637
(5,443)
$ 3,792
(a) Other revenue sources relate to revenues from customers accounted for as derivatives and leases, alternative revenue programs at Southern Company
Gas, and cost recovery mechanisms and revenues that meet other scope exceptions for revenues from contracts with customers at the traditional electric
operating companies.
(b) Other adjustments relate to the cost of Southern Company Gas’ energy and risk management activities. Wholesale gas services revenues are presented net
of the related costs of those activities on the statement of income. See Notes 15 and 16 under “Southern Company Gas” for information on the sale of
Sequent and components of wholesale gas services’ operating revenues, respectively.
120
Southern Company 2021 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, 2021 and 2020:
Accounts Receivable
At December 31, 2021
At December 31, 2020
Contract Assets
At December 31, 2021
At December 31, 2020
Contract Liabilities
At December 31, 2021
At December 31, 2020
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
$2,504
2,614
$ 117
158
$
57
61
$589
632
$
$
2
2
4
6
(in millions)
$736
806
$ 63
71
$ 14
27
$ 73
77
$ —
—
$ —
1
$149
112
$
$
1
—
1
1
$ 753
788
$ —
—
$ —
1
At December 31, 2021 and 2020, Georgia Power had contract assets primarily related to retail customer fixed bill programs, where
the payment is contingent upon Georgia Power’s continued performance and the customer’s continued participation in the program
over a one-year contract term, and unregulated service agreements, where payment is contingent on project completion. Contract
liabilities for Georgia Power relate to cash collections recognized in advance of revenue for unregulated service agreements. Southern
Company’s unregulated distributed generation business had contract assets of $50 million and $81 million at December 31, 2021 and
2020, respectively, and contract liabilities of $39 million and $27 million at December 31, 2021 and 2020, respectively, for outstanding
performance obligations.
Revenues recognized in 2021 and 2020, which were included in contract liabilities at December 31, 2020 and December 31, 2019,
respectively, were $29 million and $33 million, respectively, for Southern Company and immaterial for the other Registrants.
Remaining Performance Obligations
The traditional electric operating companies and Southern Power have long-term contracts with customers in which revenues are
recognized as performance obligations are satisfied over the contract term. These contracts primarily relate to PPAs whereby the traditional
electric operating companies and Southern Power provide electricity and generation capacity to a customer. The revenue recognized for the
delivery of electricity is variable; however, certain PPAs include a fixed payment for fixed generation capacity over the term of the contract.
Southern Company’s unregulated distributed generation business also has partially satisfied performance obligations related to certain
fixed price contracts. Revenues from contracts with customers related to these performance obligations remaining at December 31, 2021
are expected to be recognized as follows:
Southern Company
Alabama Power
Georgia Power
Southern Power
2022
$ 577
33
68
331
2023
$ 462
24
48
293
(in millions)
2024
$ 341
7
25
309
2025
2026
Thereafter
$ 319
5
22
292
$ 295
—
11
287
$ 2,309
—
31
2,294
Revenue expected to be recognized for performance obligations remaining at December 31, 2021 was immaterial for Mississippi Power.
121
Southern Company 2021 Annual Report Notes to Financial Statements
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.
The Registrants’ property, plant, and equipment in service consisted of the following at December 31, 2021 and 2020:
At December 31, 2021:
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 distribution utilities
transportation and distribution
Storage facilities
Other
Southern Company Gas plant in service
Other plant in service
Total plant in service
$ 53,803
13,406
22,236
5,423
94,868
15,714
1,315
1,851
18,880
1,844
$115,592
$16,631
5,334
8,643
2,527
33,135
—
—
—
—
—
$33,135
$19,184
7,132
12,437
2,579
41,332
—
—
—
—
—
$41,332
$2,791
900
1,156
259
5,106
—
—
—
—
—
$5,106
$14,551
—
—
34
14,585
—
—
—
—
—
$14,585
$
—
—
—
—
—
15,714
1,315
1,851
18,880
—
$18,880
At December 31, 2020:
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 distribution utilities transportation
and distribution
Storage facilities
Other
Southern Company Gas plant in service
Other plant in service
Total plant in service
$ 52,179
12,879
20,958
5,072
91,088
14,610
1,752
1,249
17,611
1,817
$110,516
$16,201
5,033
8,248
2,334
31,816
—
—
—
—
—
$31,816
$18,675
6,951
11,622
2,434
39,682
—
—
—
—
—
$39,682
$2,819
856
1,088
248
5,011
—
—
—
—
—
$5,011
$13,872
—
—
32
13,904
—
—
—
—
—
$13,904
$
—
—
—
—
—
14,610
1,752
1,249
17,611
—
$ 17,611
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 and 2 and 24 months for Plant Hatch Units 1 and 2. Georgia Power’s amortization period begins the month the refueling
outage starts.
122
Southern Company 2021 Annual Report Notes to Financial Statements
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.
The Registrants have deferred certain implementation costs related to cloud hosting arrangements. 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. At December 31, 2021 and 2020,
deferred cloud implementation costs, which are generally included in other deferred charges and assets on the Registrants’ balance sheets, are
as follows:
Deferred cloud implementation costs:
At December 31, 2021
At December 31, 2020
Depreciation and Amortization
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
$240
162
$54
38
$81
58
$ 11
7
$ 14
9
$35
17
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 2021, 2020, and 2019 are as follows:
Alabama Power
Georgia Power
Mississippi Power
Southern Company Gas
2021
2020
2019
2.7 %
3.3 %
3.6 %
2.8 %
2.6%
3.0%
3.7 %
2.8 %
3.1 %
2.6 %
3.7%
2.9 %
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. During 2020, Georgia Power, Mississippi Power, and Atlanta Gas Light revised their depreciation rates in accordance with base rate
case approvals by their respective PSCs. The revised rates were effective January 1, 2020 for Georgia Power and Atlanta Gas Light and April
1, 2020 for Mississippi Power. 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, 2021 and 2020, accumulated depreciation for Southern Company and Southern Company Gas consisted of utility plant
in service totaling $33.1 billion and $31.6 billion, respectively, for Southern Company and $4.8 billion and $4.6 billion, respectively, for
Southern Company Gas, as well as other plant in service totaling $930 million and $817 million, respectively, for Southern Company and
$219 million and $195 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 37 years.
123
Southern Company 2021 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 30 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, 2021, 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)
Plant Vogtle (nuclear) Units 1 and 2
Plant Scherer (coal) Units 1 and 2
Plant Scherer (coal) Unit 3
Plant Wansley (coal)
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
2,133
50.1 % (c)
45.7 (c)
8.4 (c)
75.0 (c)
53.5 (c)
25.4 (d)
$1,382
3,611
276
1,314
1,070
184
40.0 % (a)
50.0 (e)
$ 124
762
$
79
665
$ 647
2,265
100
539
472
148
$
61
237
$ 1
15
$42
86
1
8
7
1
$ —
19
50.0 % (f)
$ 271
$
19
$ —
(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 Units 1 and 2, Scherer, and Wansley in varying amounts jointly with one or more of the
following entities: OPC, MEAG Power, Dalton, Florida Power & Light Company, JEA, and Gulf Power. 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) Jointly owned with OPC, which is the operator of the plant.
(e) Jointly owned by Gulf Power and Mississippi Power. In accordance with the operating agreement, Mississippi Power acts as Gulf Power’s agent with
respect to the operation and maintenance of these units. See Note 3 under “Other Matters – Mississippi Power – Plant Daniel” for information regarding a
commitment between Mississippi Power and Gulf Power to seek a restructuring of their 50% undivided ownership interests in Plant Daniel.
(f) 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.
124
Southern Company 2021 Annual Report Notes to Financial Statements
Georgia Power also owns 45.7% of Plant Vogtle Units 3 and 4, which are currently under construction and had a CWIP balance of $8.6 billion
at December 31, 2021, excluding estimated probable losses recorded in 2018, 2020, and 2021. See Note 2 under “Georgia Power – Nuclear
Construction” for additional information.
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.
Assets Subject to Lien
In 2018, the Mississippi PSC approved executed agreements between Mississippi Power and its largest retail customer, Chevron Products
Company (Chevron), for Mississippi Power to continue providing 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, with a lease
receivable balance of $167 million at December 31, 2021, 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.
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 and 2). 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.
125
Southern Company 2021 Annual Report Notes to Financial Statements
Details of the AROs included in the balance sheets are as follows:
Balance at December 31, 2019
$ 9,786
$ 3,540
$ 5,784
$ 190
$ 89
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power(*)
(in millions)
Liabilities incurred
Liabilities settled
Accretion
Cash flow revisions
Balance at December 31, 2020
Liabilities incurred
Liabilities settled
Accretion
Cash flow revisions
Balance at December 31, 2021
19
(442 )
409
912
$ 10,684
26
(456 )
407
1,026
—
(219 )
152
501
$3,974
—
(202 )
156
406
10
(185 )
238
418
$ 6,265
3
(210 )
236
530
—
(22 )
8
—
$ 176
—
(24 )
7
31
9
—
4
(7)
$ 95
23
—
5
8
$ 11,687
$4,334
$ 6,824
$ 190
$131
(*) Included in other deferred credits and liabilities on Southern Power’s consolidated balance sheets.
During 2020, Alabama Power recorded increases totaling approximately $501 million to its AROs related to the CCR Rule and the related
state rule primarily as a result of management’s completion of the closure design for the remaining ash pond and the addition of a water
treatment system to the design of another ash pond. The additional estimated costs to close these ash ponds under the planned closure-
in-place methodology primarily relate to inputs from contractor bids, design revisions, and changes in the expected volume of ash handling.
During 2021, Alabama Power recorded increases totaling approximately $406 million to its AROs primarily related to the CCR Rule and the
related state rule based on updated estimates for post-closure costs at its ash ponds and inflation rates.
During the third quarter 2020, Georgia Power refined the cost estimates related to its plans to close the ash ponds at all of its generating
plants in compliance with the CCR Rule and the related state rule, including updates to long-term post-closure care requirements, market
pricing, and timing of future cash outlays and recorded an increase of approximately $411 million to its AROs related to the CCR Rule and
the related state rule. In September 2021, Georgia Power recorded a further increase of approximately $435 million to these AROs based
on updated estimates for inflation rates and the timing of closure activities.
In September 2021, Mississippi Power recorded an increase of approximately $31 million to its AROs related to the CCR Rule based on
updated estimates for the timing of closure activities, post-closure costs at one of its ash ponds, and inflation rates.
The cost estimates for AROs related to the disposal of CCR are based on information at December 31, 2021 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. 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 Note 2 under “Georgia Power – Rate Plans” for additional
information. The ultimate outcome of these matters cannot be determined at this time.
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.
126
Southern Company 2021 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.
The Funds at Georgia Power participate in a securities lending program through the managers of the Funds. Under this program, Georgia
Power’s Funds’ investment securities are loaned to institutional investors for a fee. Securities loaned are 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, 2021 and
2020, approximately $42 million and $44 million, respectively, 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. The fair value of the collateral received was approximately
$43 million and $45 million at December 31, 2021 and 2020, respectively, and can only be sold by the borrower upon the return of the
loaned securities. The collateral received is treated as a non-cash item in the statements of cash flows.
Investment securities in the Funds for December 31, 2021 and 2020 were as follows:
At December 31, 2021:
Equity securities
Debt securities
Other securities
Total investment securities in the Funds
At December 31, 2020:
Equity securities
Debt securities
Other securities
Total investment securities in the Funds
Southern
Company
Alabama
Power
(in millions)
$ 1,358
986
197
$ 2,541
$ 1,339
851
111
$ 2,301
$ 849
316
159
$1,324
$ 842
231
83
$1,156
Georgia
Power
$ 509
670
38
$ 1,217
$ 497
620
28
$ 1,145
These amounts exclude receivables related to investment income and pending investment sales and payables related to pending
investment purchases. For Southern Company and Georgia Power, these amounts include Georgia Power’s investment securities pledged to
creditors and collateral received and excludes payables related to Georgia Power’s securities lending program.
The fair value increases (decreases) of the Funds, including unrealized gains (losses) and reinvested interest and dividends and excluding the
Funds’ expenses, for 2021, 2020, and 2019 are shown in the table below.
Fair value increases
2021
2020
2019
Unrealized gains (losses)
At December 31, 2021
At December 31, 2020
At December 31, 2019
Southern
Company
Alabama
Power
(in millions)
$ 274
280
344
$ (27)
220
259
$200
142
194
$ (30)
121
149
Georgia
Power
$ 74
138
150
$
3
99
110
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.
127
Southern Company 2021 Annual Report Notes to Financial Statements
For Alabama Power, approximately $15 million at each of December 31, 2021 and 2020 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.
At December 31, 2021 and 2020, 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
Total
2021
2020
(in millions)
$1,324
$ 1,156
$ 757
460
$1,217
$ 716
429
$ 1,145
Site study cost is the estimate to decommission a specific facility as of the site study year. The decommissioning cost estimates are based
on prompt dismantlement and removal of the plant from service. 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, 2021 based on the most current studies, which were performed
in 2018 for Alabama Power and in 2021 for Georgia Power, were as follows:
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
Farley
2037
2076
$1,234
387
99
$1,720
Plant
Hatch(*)
Plant Vogtle
Units 1 and 2(*)
2034
2075
(in millions)
$ 771
186
61
$ 1,018
2047
2079
$628
170
85
$883
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 as of 2021. Significant assumptions used to determine these costs for ratemaking were an estimated inflation rate of 4.5%
and 2.5% for Alabama Power and Georgia Power, respectively, and an estimated trust earnings rate of 7.0% and 4.5% for Alabama Power
and Georgia Power, respectively.
Amounts previously contributed to the Funds for Plant Farley are currently projected to be adequate to meet the decommissioning
obligations. Alabama Power will continue to provide site-specific estimates of the decommissioning costs and related projections of funds
in the external trust to the Alabama PSC and, if necessary, would seek the Alabama PSC’s approval to address any changes in a manner
consistent with NRC and other applicable requirements.
Effective January 1, 2020, in connection with the 2019 ARP, Georgia Power’s annual decommissioning cost for ratemaking is a total
of $4 million for Plant Hatch and Plant Vogtle Units 1 and 2. Georgia Power’s annual decommissioning cost for ratemaking in 2019
totaled $5 million.
128
Southern Company 2021 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.
SEGCO
Alabama Power and Georgia Power own equally all of the outstanding capital stock of SEGCO, which owns electric generating units
with a total rated capacity of 1,020 MWs, as well as associated transmission facilities. 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 $75 million
in 2021, $67 million in 2020, and $93 million in 2019 for Alabama Power and $77 million in 2021, $69 million in 2020, and $95 million in
2019 for Georgia Power.
SEGCO paid dividends of $14 million in 2021, $12 million in 2020, and $14 million in 2019, 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
In 2018, Southern Power sold a noncontrolling 33% limited partnership interest in SP Solar to Global Atlantic Financial Group Limited
(Global Atlantic). A wholly-owned subsidiary of Southern Power is the general partner and holds a 1% ownership interest in SP Solar and
another wholly-owned subsidiary of Southern Power owns the remaining 66% ownership in SP Solar. 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, 2021 and 2020, SP Solar had total assets of $6.1 billion, total liabilities of $408 million and $387 million, respectively, and
noncontrolling interests of $1.1 billion. Cash distributions from SP Solar are allocated 67% to Southern Power and 33% to Global Atlantic in
accordance with their partnership interest percentage. Under the terms of the limited partnership agreement, distributions without limited
partner consent are limited to available cash and SP Solar is obligated to distribute all such available cash to its partners each quarter.
Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves.
129
Southern Company 2021 Annual Report Notes to Financial Statements
In 2018, Southern Power sold a noncontrolling tax equity interest in SP Wind to three financial investors. 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, 2021 and 2020, SP Wind had total assets of $2.3 billion and $2.4 billion, respectively, total liabilities of $130 million
and $138 million, respectively, and noncontrolling interests of $41 million and $43 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, 2021 and 2020, the other VIEs had total assets of $1.9 billion and $1.1 billion, respectively, total liabilities of $263 million
and $110 million, respectively, and noncontrolling interests of $886 million and $454 million, respectively. Under the terms of the partnership
agreements, distributions of all available cash are required each month or quarter and additional distributions require partner consent.
Equity Method Investments
At December 31, 2021 and 2020, Southern Power had equity method investments in wind and battery energy storage projects totaling
$86 million and $19 million, respectively. Earnings (loss) from these investments were immaterial for all periods presented. Subsequent to
December 31, 2021, Southern Power sold an equity method investment in a wind project and received proceeds of $31 million. The gain
associated with the transaction was immaterial.
Southern Company Gas
Equity Method Investments
The carrying amounts of Southern Company Gas’ equity method investments at December 31, 2021 and 2020 and related earnings (loss)
from those investments for the years ended December 31, 2021, 2020, and 2019 were as follows:
Investment Balance
SNG(a)
PennEast Pipeline(b)
Other
Total
December 31, 2021
December 31, 2020
(in millions)
$1,129
11
33
$1,173
$ 1,167
91
32
$ 1,290
(a) Decrease primarily relates to the continued amortization of deferred tax assets established upon acquisition, as well as distributions in excess of earnings.
(b) Investment balance at December 31, 2021 reflects pre-tax impairment charges totaling $84 million recorded during 2021. See “PennEast Pipeline Project”
herein for additional information, including the September 2021 cancellation of the project.
130
Southern Company 2021 Annual Report Notes to Financial Statements
Earnings (Loss) from Equity Method Investments
SNG
Atlantic Coast Pipeline(a)(b)
PennEast Pipeline(a)(c)
Other(d)
Total
2021
$127
—
(81)
4
$ 50
2020
(in millions)
$129
3
7
2
$141
2019
$141
13
6
(3)
$157
(a) Earnings primarily result from AFUDC equity recorded by the project entity.
(b) In March 2020, Southern Company Gas completed the sale of its interest in Atlantic Coast Pipeline. See Note 15 under “Southern Company Gas” for
additional information.
(c) 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.
(d) In March 2020, Southern Company Gas completed the sale of its interest in Pivotal LNG. See Note 15 under “Southern Company Gas” for additional information.
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. On June 29, 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).
On September 27, 2021, PennEast Pipeline announced that further development of the project is no longer supported, and, as a result,
all further development of the project has 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.
131
Southern Company 2021 Annual Report Notes to Financial Statements
8. FINANCING
Long-term Debt
Details of long-term debt at December 31, 2021 and 2020 are provided in the following table:
At December 31, 2021
Maturity
Weighted Average
Interest Rate
Balance Outstanding at
December 31,
2021
2020
(in millions)
2022-2052
2024-2081
2022-2044
2022-2053
2023-2060
2022-2027
2022-2026
3.62%
4.00%
2.88%
1.05%
3.53%
7.60%
0.79%
2022-2052
2024-2038
2026
3.89%
0.55%
1.24%
2022-2051
2077
2022-2044
2022-2053
2022
3.61%
5.00%
2.88%
1.33%
0.70%
$33,120
8,918
4,962
2,662
2,100
130
270
—
—
215
359
(216)
(243)
52,277
2,157
$50,120
$ 8,725
995
45
—
4
(18)
(64)
9,687
751
$ 8,936
$ 6,825
270
4,962
1,591
125
136
(11)
(114)
13,784
675
$13,109
$30,850
7,295
4,618
2,675
1,900
160
370
320
206
231
393
(201)
(237)
48,580
3,507
$45,073
$ 7,625
1,060
45
206
5
(16)
(56)
8,869
311
$ 8,558
$ 6,400
270
4,618
1,538
125
145
(12)
(114)
12,970
542
$12,428
Southern Company
Senior notes(a)
Junior subordinated notes
FFB loans(b)
Pollution control revenue bonds(c)
First mortgage bonds(d)
Medium-term notes
Other long-term debt
Other revenue bonds
Debt payable to affiliated trusts(e)
Finance lease obligations(f)
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
Pollution control revenue bonds(c)
Other long-term debt
Debt payable to affiliated trusts(e)
Finance lease obligations(f)
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)
Pollution control revenue bonds(c)
Other long-term debt
Finance lease obligations(f)
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
132
Southern Company 2021 Annual Report
Notes to Financial Statements
Mississippi Power
Senior notes
Pollution control revenue bonds(c)
Other revenue bonds
Other long-term debt
Finance lease obligations(f)
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
Unamortized fair value adjustment
Unamortized debt premium (discount), net
Total long-term debt
Less: Amount due within one year
Total long-term debt excluding amount due within one year
At December 31, 2021
Maturity
Weighted Average
Interest Rate
2024-2051
2025-2028
3.43%
1.86%
2022-2046
3.74%
2023-2051
2023-2060
2022-2027
3.96%
3.53%
7.60%
Balance Outstanding at
December 31,
2021
2020
(in millions)
$ 1,425
76
—
—
18
2
(10)
1,511
1
$ 1,510
$ 3,711
(6)
(17)
3,688
679
$ 3,009
$ 4,348
2,100
130
359
(35)
6,902
47
$ 6,855
$
900
76
320
100
19
11
(7)
1,419
406
$ 1,013
$ 3,714
(6)
(16)
3,692
299
$ 3,393
$ 4,200
1,900
160
393
(27)
6,626
333
$ 6,293
(a) Includes a fair value gain (loss) of $5 million and $109 million at December 31, 2021 and 2020, respectively, related to Southern Power’s foreign currency
hedge on its €1.1 billion 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 under construction, the
related real property, and any nuclear fuel loaded in the reactor core) and (ii) Georgia Power’s rights and obligations under the principal contracts relating to
Plant Vogtle Units 3 and 4. See “DOE Loan Guarantee Borrowings” herein for additional information.
(c) Pollution control 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 facilities. In some cases, the pollution control
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) At December 31, 2020, Alabama Power had a wholly-owned trust subsidiary for the purpose of issuing preferred securities. The proceeds of the related
equity investments and preferred security sales were loaned back to Alabama Power through the issuance of junior subordinated notes, which Alabama
Power redeemed during 2021. The junior subordinated notes constituted substantially all of the assets of this trust. Alabama Power considered the
mechanisms and obligations relating to the preferred securities issued for its benefit, taken together, constituted a full and unconditional guarantee by it of
the trust’s payment obligations with respect to these securities. See Note 1 under “Variable Interest Entities” for additional information on the accounting
treatment for this trust and the related securities.
(f) Secured by the underlying lease ROU asset. See Note 9 for additional information.
133
Southern Company 2021 Annual Report
Notes to Financial Statements
Maturities of long-term debt for the next five years are as follows:
2022
2023
2024
2025
2026
Southern
Company(a)
Alabama
Power
Georgia
Power(b)
Mississippi
Power
Southern
Power(c)
Southern
Company Gas
(in millions)
$2,157
3,738
2,280
1,199
3,723
$751
301
22
250
45
$676
897
498
145
441
$
1
1
201
11
1
$ 677
290
—
500
964
$ 46
400
—
300
530
(a) Amount for 2022 excludes junior subordinated notes totaling $1.725 billion at the parent entity that Southern Company has agreed to remarket in 2022
in connection with the related stock purchase contracts; however, the final maturity dates are in 2024 and 2027 (one half in each year). See “Equity Units”
herein for additional information. Also see notes (b) and (c) below.
(b) 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.
(c) Southern Power’s 2022 maturity and $564 million of its 2026 maturities represent 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 March 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 June 2021 and December 2021, Georgia Power made the final borrowings under the FFB Credit Facilities in aggregate principal amounts
of $371 million and $69 million, respectively, at an interest rate of 2.434% and 2.178%, respectively, through the final maturity date
of February 20, 2044. No further borrowings are permitted under the FFB Credit Facilities. During 2021, Georgia Power made principal
amortization payments of $96 million under the FFB Credit Facilities. At December 31, 2021 and 2020, Georgia Power had $5.0 billion and
$4.6 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 under construction, the related real property, and any nuclear fuel loaded in the reactor core) and (ii) Georgia Power’s rights and
obligations under the principal contracts relating to Plant Vogtle Units 3 and 4. There are no restrictions on Georgia Power’s ability to grant
liens on other property.
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 February 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, unless the Vogtle Owners enter into a replacement agreement; (iii) cancellation
of Plant Vogtle Units 3 and 4 by the Georgia PSC or by Georgia Power; (iv) failure of the holders of 90% of the ownership interests in Plant
Vogtle Units 3 and 4 to vote to continue construction following certain schedule extensions; (v) cost disallowances by the Georgia PSC
that could have a material adverse effect on completion of Plant Vogtle Units 3 and 4 or Georgia Power’s ability to repay the outstanding
borrowings under the FFB Credit Facilities; or (vi) loss of or failure to receive necessary regulatory approvals. Under certain circumstances,
insurance proceeds and any proceeds from an event of taking must be applied to immediately prepay outstanding borrowings under the
134
Southern Company 2021 Annual Report Notes to Financial Statements
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.
The latest extension of the schedule for Plant Vogtle Units 3 and 4 triggers the requirement that the holders of at least 90% of the
ownership interests of Plant Vogtle Units 3 and 4 must vote to continue construction. If the holders of at least 90% of the ownership
interests of Plant Vogtle Units 3 and 4 do not vote to continue construction, the DOE may require Georgia Power to prepay all outstanding
borrowings under the FFB Credit Facilities over a period of five years.
In connection with any cancellation of Plant Vogtle Units 3 and 4, the DOE may elect to continue construction of Plant Vogtle Units 3
and 4. In such an event, the DOE will have the right to assume Georgia Power’s rights and obligations under the principal agreements
relating to Plant Vogtle Units 3 and 4 and to acquire all or a portion of Georgia Power’s ownership interest in Plant Vogtle Units 3 and 4.
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, 2021 and 2020. Each
Registrant’s senior notes, junior subordinated notes, pollution control and other 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 2019, Southern Company issued 34.5 million 2019 Series A Equity Units (Equity Units), initially in the form of corporate units (Corporate
Units), at a stated amount of $50 per Corporate Unit, for a total stated amount of $1.725 billion. Net proceeds from the issuance were
approximately $1.682 billion. The proceeds were used to repay short-term indebtedness and for other general corporate purposes,
including investments in Southern Company’s subsidiaries.
Each Corporate Unit is comprised of (i) a 1/40 undivided beneficial ownership interest in $1,000 principal amount of Southern Company’s
Series 2019A Remarketable Junior Subordinated Notes (Series 2019A RSNs) due 2024, (ii) a 1/40 undivided beneficial ownership interest
in $1,000 principal amount of Southern Company’s Series 2019B Remarketable Junior Subordinated Notes (together with the Series 2019A
RSNs, the RSNs) due 2027, and (iii) a stock purchase contract, which obligates the holder to purchase from Southern Company, no later
than August 1, 2022, a certain number of shares of Southern Company’s common stock for $50 in cash (Stock Purchase Contract). Southern
Company has agreed to remarket the RSNs in 2022, at which time each interest rate on the RSNs will reset at the applicable market rate.
Holders may choose to either remarket their RSNs, receive the proceeds, and use those funds to settle the related Stock Purchase Contract
or retain the RSNs and use other funds to settle the related Stock Purchase Contract. If the remarketing is unsuccessful, holders will have
the right to put their RSNs to Southern Company at a price equal to the principal amount. The Corporate Units carry an annual distribution
rate of 6.75% of the stated amount, which is comprised of a quarterly interest payment on the RSNs of 2.70% per year and a quarterly
purchase contract adjustment payment of 4.05% per year.
Each Stock Purchase Contract obligates the holder to purchase, and Southern Company to sell, for $50 a number of shares of Southern
Company common stock determined based on the applicable market value (as determined under the related Stock Purchase Contract) in
accordance with the conversion ratios set forth below (subject to anti-dilution adjustments):
O If the applicable market value is equal to or greater than $68.64, 0.7284 shares.
O If the applicable market value is less than $68.64 but greater than $57.20, a number of shares equal to $50 divided by the applicable
market value.
O If the applicable market value is less than or equal to $57.20, 0.8741 shares.
A holder’s ownership interest in the RSNs is pledged to Southern Company to secure the holder’s obligation under the related Stock
Purchase Contract. If a holder of a Stock Purchase Contract chooses at any time to have its RSNs released from the pledge, such holder’s
obligation under such Stock Purchase Contract must be secured by a U.S. Treasury security equal to the aggregate principal amount of
the RSNs. At the time of issuance, the RSNs were recorded on Southern Company’s consolidated balance sheet as long-term debt and the
present value of the contract adjustment payments of $198 million was recorded as a liability, representing the obligation to make contract
adjustment payments, with an offsetting reduction to paid-in capital. The liability balance at December 31, 2021 was $52 million, which
was classified as current. The difference between the face value and present value of the contract adjustment payments is being accreted
to interest expense on the consolidated statements of income over the three-year period ending in August 2022. The liability recorded
for the contract adjustment payments is considered non-cash and excluded from the consolidated statements of cash flows. To settle the
135
Southern Company 2021 Annual Report Notes to Financial Statements
Stock Purchase Contracts, Southern Company will be required to issue a maximum of 30.2 million shares of common stock (subject to
anti-dilution adjustments and a make-whole adjustment if certain fundamental changes occur).
Bank Credit Arrangements
At December 31, 2021, committed credit arrangements with banks were as follows:
Company
2022
2023
2024
2026
Total
Unused
Expires
Southern Company parent
Alabama Power
Georgia Power
Mississippi Power
Southern Power(a)
Southern Company Gas(b)
SEGCO
Southern Company
$ —
—
—
—
—
250
30
$280
$ —
—
—
125
—
—
—
$125
$ —
550
—
150
—
—
—
$700
(in millions)
$2,000
700
1,750
—
600
1,500
—
$6,550
$2,000
1,250
1,750
275
600
1,750
30
$7,655
$1,998
1,250
1,726
275
568
1,747
30
$7,594
Due within
One Year
$ —
—
—
—
—
250
30
$280
(a) Does not include Southern Power Company’s $75 million and $60 million continuing letter of credit facilities for standby letters of credit expiring in 2023,
of which $8 million and $4 million, respectively, was unused at December 31, 2021. Subsequent to December 31, 2021, Southern Power amended its
$60 million letter of credit facility, which, among other things, extended the expiration date from 2023 to 2025 and increased the amount to $75 million.
Southern Power’s subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.
(b) Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $800 million of the
arrangement expiring in 2026 and all $250 million of the arrangement expiring in 2022. Southern Company Gas’ committed credit arrangement expiring
in 2026 also includes $700 million for which Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. Pursuant to the
multi-year credit arrangement expiring in 2026, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted. 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 or, in the case of Southern Power, cross-default provisions to other indebtedness
(including guarantee obligations) that are restricted only to the indebtedness of the individual company. Such cross-default provisions
to other indebtedness would trigger an event of default if Southern Power defaulted on indebtedness or guarantee obligations over a
specified threshold. Such cross-acceleration provisions to other indebtedness would trigger an event of default if the applicable borrower
defaulted on indebtedness, the payment of which was then accelerated. Southern Company’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, 2021, the Registrants, Nicor Gas, and SEGCO were in compliance
with all such covenants. None of the bank credit arrangements contain material adverse change clauses at the time of borrowings.
A portion of the unused credit with banks is allocated to provide liquidity support to the revenue bonds of the traditional electric
operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. The amount of variable rate revenue
bonds of the traditional electric operating companies outstanding requiring liquidity support at December 31, 2021 was approximately
$1.5 billion (comprised of approximately $789 million at Alabama Power, $672 million at Georgia Power, and $34 million at Mississippi
Power). In addition, at December 31, 2021, Georgia Power had approximately $157 million of fixed rate revenue bonds outstanding that
are required to be remarketed within the next 12 months.
At both December 31, 2021 and 2020, Southern Power had $105 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.
136
Southern Company 2021 Annual Report Notes to Financial Statements
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, 2021
Notes Payable at December 31, 2020
Amount
Outstanding
(in millions)
Weighted Average
Interest Rate
Amount
Outstanding
(in millions)
Weighted Average
Interest Rate
Southern Company
Commercial paper
Short-term bank debt
Total
Georgia Power
Commercial paper
Mississippi Power
Commercial paper
Southern Power
Commercial paper
Southern Company Gas
Commercial paper:
Southern Company Gas Capital
Nicor Gas
Short-term bank debt:
Nicor Gas
Total
$1,140
300
$1,440
$ —
$ —
0.3 %
0.7 %
0.4 %
— %
— %
$609
—
$609
$ 60
$ 25
$ 211
0.3 %
$175
$ 379
530
300
$1,209
0.3 %
0.3 %
0.7 %
0.4 %
$220
104
—
$324
0.3%
—%
0.3%
0.3%
0.4%
0.3%
0.3%
0.2%
—%
0.2%
See “Bank Credit Arrangements” herein for information on bank term loan covenants that limit debt levels and cross-acceleration or cross-
default provisions.
Outstanding Classes of Capital Stock
Southern Company
Common Stock
Stock Issued
During 2021, Southern Company issued approximately 3.5 million shares of common stock primarily through employee equity
compensation plans and received proceeds of approximately $73 million.
See “Equity Units” herein for additional information.
137
Southern Company 2021 Annual Report Notes to Financial Statements
Shares Reserved
At December 31, 2021, a total of 127 million shares were reserved for issuance pursuant to the Southern Investment Plan, employee
savings plans, the Outside Directors Stock Plan, the Equity and Incentive Compensation Plan (which includes stock options and
performance share units as discussed in Note 12), and an at-the-market program. Of the total 127 million shares reserved, 31.5 million
shares are available for awards under the Equity and Incentive Compensation Plan at December 31, 2021.
Diluted Earnings Per Share
For Southern Company, the only differences in computing basic and diluted earnings per share (EPS) are attributable to awards outstanding
under stock-based compensation plans and the Equity Units. Earnings per share dilution resulting from stock-based compensation plans
and the Equity Units issuance is determined using the treasury stock method. Shares used to compute diluted EPS were as follows:
As reported shares
Effect of stock-based compensation
Diluted shares
Average Common Stock Shares
2021
1,061
7
1,068
2020
(in millions)
1,058
7
1,065
2019
1,046
8
1,054
In all years presented, an immaterial number of stock-based compensation awards was not included in the diluted EPS calculation because
the awards were anti-dilutive.
The Equity Units were excluded from the calculation of diluted EPS for all years presented as the dilutive stock price threshold was
not met.
Redeemable Preferred Stock of Subsidiaries
As discussed further under “Alabama Power” herein, the preferred stock of Alabama Power is presented as “Redeemable Preferred Stock of
Subsidiaries” on Southern Company’s balance sheets in a manner consistent with temporary equity under applicable accounting standards.
Alabama Power
Alabama Power has preferred stock, Class A preferred stock, and common stock outstanding. Alabama Power also has authorized preference
stock, none of which is outstanding. Alabama Power’s preferred stock and Class A preferred stock, without preference between classes, rank
senior to Alabama Power’s common stock with respect to payment of dividends and voluntary and involuntary dissolution. The preferred
stock and Class A preferred stock of Alabama Power contain a feature that allows the holders to elect a majority of Alabama Power’s board
of directors if preferred dividends are not paid for four consecutive quarters. Because such a potential redemption-triggering event is not
solely within the control of Alabama Power, the preferred stock and Class A preferred stock is presented as “Redeemable Preferred Stock”
on Alabama Power’s balance sheets in a manner consistent with temporary equity under applicable accounting standards.
Alabama Power’s preferred stock is subject to redemption at a price equal to the par value plus a premium. Alabama Power’s Class A
preferred stock is subject to redemption at a price equal to the stated capital. All series of Alabama Power’s preferred stock currently are
subject to redemption at the option of Alabama Power. The Class A preferred stock is subject to redemption on or after October 1, 2022,
or following the occurrence of a rating agency event. Information for each outstanding series is in the table below:
Par Value/Stated
Capital Per Share
Shares
Outstanding
Redemption
Price Per Share
$100
$100
$100
$100
$100
$100
$ 25
80,000
50,000
60,000
100,000
50,000
135,115
10,000,000
$103.23
$102.18
$103.14
$104.20
$102.93
$105.00
$ 25.00(*)
Preferred Stock
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
(*) $25.50 if prior to October 1, 2022
138
Southern Company 2021 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, 2021, consolidated
retained earnings included $4.4 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, to the extent of its retained earnings balance, in the amount it can dividend or loan to affiliates and
is not permitted to make money pool loans to affiliates. At December 31, 2021, the amount of Southern Company Gas’ subsidiary retained
earnings restricted for dividend payment totaled $1.3 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
On January 1, 2019, the Registrants adopted the provisions of FASB ASC Topic 842 (as amended), Leases (ASC 842), which require lessees to
recognize leases with a term of greater than 12 months on the balance sheet as lease obligations, representing the discounted future fixed
payments due, along with ROU assets that will be amortized over the term of each lease.
The Registrants elected the transition methodology provided by ASC 842, whereby the applicable requirements were applied on a
prospective basis as of the adoption date. The Registrants also elected the package of practical expedients provided by ASC 842 that
allows prior determinations of whether existing contracts are, or contain, leases and the classification of existing leases to continue
without reassessment. Additionally, the Registrants applied the use-of-hindsight practical expedient in determining lease terms as of the
date of adoption and elected the practical expedient that allows existing land easements not previously accounted for as leases not to
be reassessed.
139
Southern Company 2021 Annual Report Notes to Financial Statements
Lessee
As lessee, the Registrants lease certain electric generating units (including renewable energy facilities), real estate/land, communication
towers, railcars, and other equipment and vehicles. The major categories of lease obligations are as follows:
At December 31, 2021
Electric generating units
Real estate/land
Communication towers
Railcars
Other
Total
At December 31, 2020
Electric generating units
Real estate/land
Communication towers
Railcars
Other
Total
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
$ 802
876
156
32
103
$1,969
$ 941
815
158
42
127
$2,083
$104
3
2
10
5
$124
$146
4
2
16
7
$175
$1,217
49
4
20
1
$1,291
$1,368
53
3
23
5
$1,452
$ —
2
—
2
24
$28
$ —
2
—
3
23
$28
$ —
526
—
—
—
$526
$ —
451
—
—
—
$451
$ —
45
24
—
1
$70
$ —
61
20
—
1
$82
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 24 years while the land leases have remaining terms of up to 45 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 15 years with options to renew that could extend the terms for an additional 15 years.
Renewal options exist in many of the leases. Except as otherwise noted, the expected term used in calculating the lease obligation
generally reflects only the noncancelable period of the lease as it is not considered reasonably certain that the lease will be extended.
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 17 years. Georgia Power has several PPAs with Southern Power that Georgia Power
accounts for as leases with a lease obligation of $521 million and $575 million at December 31, 2021 and 2020, 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.
Short-term Leases
Leases with an initial term of 12 months or less are not recorded on the balance sheet; the Registrants generally recognize lease expense
for these leases on a straight-line basis over the lease term.
Residual Value Guarantees
Residual value guarantees exist primarily in railcar leases at Alabama Power and Georgia Power and the amounts probable of being paid
under those guarantees are included in the lease payments. All such amounts are immaterial at December 31, 2021 and 2020.
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.
140
Southern Company 2021 Annual Report Notes to Financial Statements
Balance sheet amounts recorded for operating and finance leases are as follows:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
At December 31, 2021
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, 2020
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
$1,701
$ 250
1,503
$1,754
$ 197
16
$
199
$ 215
$1,802
$ 241
1,611
$1,852
$ 218
17
$
214
$ 231
$108
$ 54
66
$121
$
$
$
4
1
3
4
$151
$ 51
119
$170
$
$
$
5
1
4
5
$ 1,157
$ 156
999
$ 1,155
$ 104
10
$
126
$ 136
$ 1,308
$ 151
1,156
$ 1,307
$ 115
9
$
136
$ 145
$10
$ 4
6
$10
$17
$ 1
17
$18
$ 9
$ 2
7
$ 9
$19
$ 1
18
$19
$479
$ 28
497
$525
$ —
$ —
—
$ —
$415
$ 25
426
$451
$ —
$ —
—
$ —
$70
$11
59
$70
$ —
$ —
—
$ —
$81
$15
67
$82
$ —
$ —
—
$ —
(*) Includes operating lease obligations related to PPAs at Southern Company, Alabama Power, and Georgia Power totaling $802 million, $104 million, and
$1.11 billion, respectively, at December 31, 2021 and $941 million, $146 million, and $1.25 billion, respectively, at December 31, 2020.
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.
141
Southern Company 2021 Annual Report Notes to Financial Statements
Lease costs for 2021, 2020, and 2019, which includes both amounts recognized as operations and maintenance expense and amounts
capitalized as part of the cost of another asset, are as follows:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
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
2020
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
2019
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
$313
21
11
32
48
96
1
$490
$309
26
11
37
39
91
—
$476
$310
28
12
40
48
105
—
$503
$58
1
—
1
15
4
—
$78
$55
1
—
1
11
4
(1)
$70
$54
1
—
1
19
6
(1)
$79
$ 208
11
16
27
24
83
—
$ 342
$ 212
15
16
31
26
76
—
$ 345
$ 206
15
18
33
22
85
—
$ 346
$ 2
1
1
2
—
—
—
$ 4
$ 3
—
—
—
—
—
—
$ 3
$ 3
—
—
—
—
—
—
$ 3
$33
—
—
—
—
5
—
$38
$29
—
—
—
—
7
—
$36
$28
—
—
—
—
7
—
$35
$ 19
—
—
—
—
—
—
$ 19
$ 19
—
—
—
—
—
—
$ 19
$ 18
—
—
—
—
—
—
$ 18
(*) Includes operating lease costs related to PPAs at Southern Company, Alabama Power, and Georgia Power totaling $165 million, $47 million, and $184 million,
respectively, in 2021, $161 million, $43 million, and $184 million, respectively, in 2020, and $149 million, $41 million, and $174 million, respectively, in 2019.
Georgia Power has variable lease payments that are based on the amount of energy produced by certain renewable generating facilities
subject to PPAs, including $41 million, $39 million, and $42 million in 2021, 2020, and 2019, respectively, from finance leases which are
included in purchased power on Georgia Power’s statements of income, $20 million of which was included in purchased power, affiliates
for all periods presented.
142
Southern Company 2021 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
Southern
Company Gas
(in millions)
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 in exchange for new operating lease
obligations
ROU assets obtained in exchange for new finance lease
obligations
2020
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 in exchange for new operating lease
obligations
ROU assets obtained in exchange for new finance lease
obligations
2019
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 in exchange for new operating lease
obligations
ROU assets obtained in exchange for new finance lease
obligations
$308
9
17
64
3
$310
9
22
227
10
$323
10
32
118
35
$58
—
1
3
—
$55
—
1
63
2
$54
—
1
7
2
$ 211
17
9
9
—
$ 215
18
11
32
—
$ 210
19
13
21
24
$ 2
1
1
—
—
$ 3
—
—
—
—
$ 3
—
—
—
—
$28
—
—
72
—
$28
—
—
51
—
27
—
—
2
—
$ 19
—
—
7
—
$ 18
—
—
4
—
18
—
—
19
—
143
Southern Company 2021 Annual Report Notes to Financial Statements
At December 31, 2021
Weighted-average remaining lease term in years:
Operating leases
Finance leases
Weighted-average discount rate:
Operating leases
Finance leases
At December 31, 2020
Weighted-average remaining lease term in years:
Operating leases
Finance leases
Weighted-average discount rate:
Operating leases
Finance leases
Maturities of lease liabilities are as follows:
Maturity Analysis
Operating leases:
2022
2023
2024
2025
2026
Thereafter
Total
Less: Present value discount
Operating lease obligations
Finance leases:
2022
2023
2024
2025
2026
Thereafter
Total
Less: Present value discount
Finance lease obligations
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
15.9
18.0
4.41%
4.82%
14.5
18.2
4.44%
4.79%
9.1
8.7
8.7
8.5
4.37%
3.09%
4.45%
10.81%
7.8
9.7
9.4
9.5
4.14%
3.20%
4.37%
10.81%
6.1
13.9
2.74%
2.74%
6.5
14.9
3.26%
2.74
32.8
N/A
5.20%
N/A
32.1
N/A
5.45%
N/A
10.5
N/A
3.61%
N/A
9.8
N/A
3.67%
N/A
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
At December 31, 2021
(in millions)
$ 307
238
195
174
154
1,575
2,643
889
$1,754
$
25
22
19
16
16
231
329
114
$ 215
$ 59
9
7
6
5
69
155
34
$121
$
$
2
1
1
—
—
—
4
—
4
$ 205
201
164
136
133
566
1,405
250
$1,155
$
25
25
25
25
26
83
209
73
$ 136
$ 4
2
1
1
1
2
11
1
$10
$ 2
2
2
2
1
13
22
4
$18
$
37
29
29
29
30
995
1,149
624
$ 525
$ —
—
—
—
—
—
—
—
$ —
$ 14
11
11
11
8
31
86
16
$ 70
$ —
—
—
—
—
—
—
—
$ —
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.
144
Southern Company 2021 Annual Report
Notes to Financial Statements
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 seven 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 17 years. For
Southern Power, these arrangements consist of PPAs related to electric generating units, including solar and wind facilities, accounted for
as operating leases with remaining terms of up to 25 years and PPAs related to battery energy storage facilities accounted for as sales-
type leases with remaining terms of up to 19 years. Southern Company Gas is the lessor in operating leases related to gas pipelines with
remaining terms of up to 21 years. For Southern Company, these arrangements also include PPAs related to fuel cells accounted for as
operating leases with remaining terms of up to 12 years.
Lease income for 2021, 2020, and 2019, is as follows:
2021
Lease income - interest income on sales-type leases
Lease income - operating leases
Variable lease income
Total lease income
2020
Lease income - interest income on sales-type leases
Lease income - operating leases
Variable lease income
Total lease income
2019
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
Southern
Company
Gas
(in millions)
$ 15
223
429
$667
$ 16
208
419
$643
$
9
273
403
$685
$ —
82
—
$82
$ —
45
—
$45
$ —
24
—
$24
$ —
42
—
$42
$ —
58
—
$58
$ —
71
—
$71
$14
2
—
$16
$12
2
—
$14
$ 9
—
—
$ 9
$
1
85
456
$542
$ —
87
449
$536
$ —
160
434
$594
$ —
35
—
$35
$ —
35
—
$35
$ —
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 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.
No profit or loss was recognized by Mississippi Power when a tolling arrangement accounted for as a sales-type lease began in 2019.
During 2020 and 2021, Mississippi Power completed construction of additional leased assets under the lease and, upon completion, the
book values of $26 million and $39 million, respectively, were transferred from CWIP to lease receivables. Each 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 has 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.
At December 31, 2021, the current portion of the lease receivables totaling $12 million is included in other current assets and the long-
term portion totaling $161 million is included in miscellaneous property and investments on Southern Company’s balance sheet and net
investment in sales-type leases on Southern Power’s consolidated balance sheet. The transfers represented noncash investing transactions
for purposes of the statement of cash flows. See Note 15 under “Southern Power” for additional information.
145
Southern Company 2021 Annual Report Notes to Financial Statements
The undiscounted cash flows expected to be received for in-service leased assets under the leases are as follows:
2022
2023
2024
2025
2026
Thereafter
Total undiscounted cash flows
Net investment in sales-type lease(*)
Difference between undiscounted cash flows and discounted cash flows
At December 31, 2021
Southern
Company
Mississippi
Power
Southern
Power
(in millions)
$ 37
39
38
37
36
390
$577
340
$237
$ 25
24
23
22
21
183
$298
167
$131
$ 12
15
15
15
15
207
$279
173
$106
(*) 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 and net investment in sales-type leases on the balance sheet.
The undiscounted cash flows to be received under operating leases and contracts accounted for as operating leases (adjusted for
intercompany eliminations) are as follows:
2022
2023
2024
2025
2026
Thereafter
Total
At December 31, 2021
Southern
Company
Alabama
Power
Georgia
Power
Southern
Power
(in millions)
$ 188
139
107
100
99
883
$1,516
$ 76
32
5
3
3
23
$142
$ 8
2
—
—
—
—
$ 10
$ 87
88
90
74
73
240
$652
Southern
Company
Gas
$ 35
35
33
28
28
407
$566
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 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, 2021, one leveraged lease agreement related to energy
generation remains, with an expected remaining term of 10 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, as discussed below.
Southern Company’s net investment in leveraged leases at December 31, 2020 consisted of the following:
Net rentals receivable
Unearned income
Investment in leveraged leases
Deferred taxes from leveraged leases
Net investment in leveraged leases
(*) Excludes the investment classified as held for sale. See Note 15 under “Southern Company” for additional information.
146
December 31, 2020(*)
(in millions)
$ 734
(178)
556
(7)
$ 549
Southern Company 2021 Annual Report Notes to Financial Statements
The following table provides a summary of the components of income related to leveraged lease investments. Income was impacted in all
periods presented 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 (loss)
Income tax benefit (expense)
Net leveraged lease income (loss)
2021
2020
2019
$17
(5)
$12
(in millions)
$(180)
98
$ (82)
$ 11
—
$ 11
Since 2017, the financial and operational performance of the remaining domestic lessee and the associated generation assets raised
significant concerns about the short-term ability of the generation assets to produce cash flows sufficient to support ongoing operations
and the lessee’s contractual obligations and its ability to make the remaining semi-annual lease payments through the end of the
lease term in 2047. In addition, following the expiration of the existing power offtake agreement in 2032, the lessee also is exposed to
remarketing risk, which encompasses the price and availability of alternative sources of generation.
In connection with the 2019 annual impairment analysis, Southern Company revised the estimated cash flows to be received under the
leveraged lease, which resulted in an impairment charge of $17 million ($13 million after tax) recorded in the fourth quarter 2019. During
the second quarter 2020, Southern Company received the latest annual forecasts of natural gas prices and considered the significant
decline in forecasted prices to be an indicator of potential impairment that required an interim impairment assessment. Accordingly,
consistent with prior impairment analyses, Southern Company evaluated the recoverability of the lease receivable and the expected
residual value of the generation assets under various natural gas price scenarios to estimate the cash flows expected to be received from
remarketing the generation assets following the expiration of the existing PPA and the residual value of the generation assets at the end of
the lease. Based on the forecasts of energy prices in the years following the expiration of the existing PPA, Southern Company concluded
that it was no longer probable that any of the associated rental payments would be received, because it was no longer probable the
generation assets would be successfully remarketed and continue to operate after that date. During the second quarter 2020, Southern
Company revised the estimated cash flows to be received under the leveraged lease to reflect this conclusion, which resulted in a full
impairment of the lease investment and a pre-tax charge to earnings of $154 million ($74 million after tax).
All required lease payments through December 31, 2021 have been paid in full. If any future lease payments due prior to the expiration
of the associated PPA are not paid in full, the Southern Holdings subsidiary may be unable to make its corresponding payment to the
holders of the underlying non-recourse debt related to the generation assets. Failure to make the required payment to the debtholders
could represent an event of default that would give the debtholders the right to foreclose on, and take ownership of, the generation assets,
in effect terminating the lease. As the remaining amount of the lease investment was charged against earnings in the second quarter
2020, termination would not be expected to result in additional charges. Southern Company will continue to monitor the operational
performance of the underlying assets and evaluate the ability of the lessee to continue to make the required lease payments and meet its
obligations associated with a future closure or retirement of the generation assets and associated properties, including the dry ash landfill.
147
Southern Company 2021 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
State —
Current
Deferred
Total
Federal —
Current
Deferred
State —
Current
Deferred
Total
Federal —
Current
Deferred
State —
Current
Deferred
Total
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
Southern
Company
Alabama
Power
Georgia
Power
2020
Mississippi
Power
(in millions)
Southern
Power
Southern
Company Gas
$ 199
70
269
100
24
124
$ 393
$198
44
242
61
34
95
$337
$ 365
(224)
141
60
(49)
11
$ 152
$ 18
(14)
4
—
10
10
$ 14
$(303)
299
(4)
(4)
11
7
3
$
$ 82
53
135
35
3
38
$ 173
Southern
Company
Alabama
Power
Georgia
Power
2019
Mississippi
Power
(in millions)
Southern
Power
Southern
Company Gas
$ 156
1,237
1,393
275
130
405
$ 1,798
$ 61
125
186
12
72
84
$270
$ 264
180
444
6
22
28
$ 472
$ (6)
26
20
(1)
11
10
$30
$(717)
647
(70)
1
13
14
$ (56)
$ (120)
195
75
37
18
55
$ 130
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 $6 million for 2021, $5 million for 2020, and $51 million for 2019.
Southern Power received $289 million, $340 million, and $734 million of cash related to federal ITCs under renewable energy initiatives in
2021, 2020, and 2019, respectively. See “Deferred Tax Assets and Liabilities” herein for additional information.
148
Southern Company 2021 Annual Report Notes to Financial Statements
In accordance with regulatory requirements, deferred federal ITCs for the traditional electric operating companies are deferred and
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 deferred and amortized to income tax expense over the life of the respective asset. ITCs amortized in
2021, 2020, and 2019 were immaterial for the traditional electric operating companies and Southern Company Gas and were as follows for
Southern Company and Southern Power:
2021
2020
2019
Southern
Company
Southern
Power
(in millions)
$ 84
84
181
$ 58
59
151
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. The tax benefit of the related basis differences reduced income tax expense by $5 million
in 2019.
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 $66 million in 2021, $67 million in 2020, and $51 million in 2019.
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 $16 million in 2021, $15 million in 2020, and $12 million in 2019.
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.
On July 1, 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.
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
2021
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
Amortization of ITC
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%
15.1
—
—
(2.8)
—
—
(0.1)
—
—
0.6
33.8%
149
Southern Company 2021 Annual Report Notes to Financial Statements
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
Amortization of ITC
Noncontrolling interests
Leveraged lease impairments
Other
Effective income tax (benefit) rate
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
ITC basis difference
Amortization of ITC
Tax impact from sale of subsidiaries
Noncontrolling interests
Other
Effective income tax (benefit) rate
2020
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
21.0%
2.8
(0.7)
0.7
(8.8)
(0.8)
—
(1.6)
—
(1.6)
0.2
11.2%
21.0%
5.0
—
0.6
(3.1)
(0.6)
—
(0.1)
—
—
(0.3)
22.5%
21.0%
0.5
—
0.8
(12.0)
(1.1)
—
(0.1)
—
—
(0.3)
8.8%
21.0%
4.8
—
0.5
(18.5)
(0.1)
—
(0.1)
—
—
0.9
8.5%
21.0%
2.7
—
—
—
—
(2.5)
(22.1)
3.1
—
(0.9)
1.3%
2019
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
21.0%
4.9
(0.4)
0.3
(2.1)
(0.4)
(0.1)
(0.8)
5.1
—
—
27.5%
21.0%
4.9
—
0.6
(5.3)
(0.8)
—
(0.1)
—
—
(0.4)
19.9%
21.0%
1.0
—
0.5
—
(0.6)
—
(0.1)
—
—
(0.3)
21.5%
21.0%
4.3
—
0.4
(12.6)
(0.1)
—
(0.1)
—
—
4.9
17.8%
21.0%
4.0
—
—
—
—
(1.9)
(16.1)
(27.6)
0.8
(0.6)
(20.4)%
Southern
Company
Gas
21.0%
4.0
—
—
(2.7)
—
—
(0.1)
—
—
0.5
22.7%
Southern
Company
Gas
21.0%
6.1
—
—
(6.0)
—
—
(0.1)
(1.4)
—
(1.4)
18.2%
150
Southern Company 2021 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:
Deferred tax liabilities —
Accelerated depreciation
Property basis differences
Federal effect of net state deferred tax assets
Leveraged lease basis differences
Employee benefit obligations
Under recovered fuel and natural gas costs
Regulatory assets –
Storm damage reserves
Employee benefit obligations
Remaining book value of retired assets
Premium on reacquired debt
AROs
AROs
Other
Total deferred income tax liabilities
Deferred tax assets —
Federal effect of net state deferred tax liabilities
State effect of federal deferred taxes
Employee benefit obligations
Other property basis differences
ITC and PTC carryforward
Long-term debt fair value adjustment
Other partnership basis difference
Other comprehensive losses
AROs
Estimated loss on plants under construction
Other deferred state tax attributes
Regulatory liability associated with the Tax Reform Legislation
(not subject to normalization)
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
December 31, 2021
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$2,541
1,182
—
—
268
47
$ 3,340
781
—
—
382
109
$ 330
169
22
—
41
15
—
205
145
10
863
329
147
5,737
165
135
225
—
12
—
—
5
1,192
—
—
18
256
121
62
1,325
494
77
6,965
41
—
342
90
704
—
—
15
1,819
825
11
—
38
5
—
44
—
34
698
—
—
57
—
—
—
—
—
44
—
246
$ 9,300
2,301
—
61
820
315
18
825
271
72
2,232
868
368
17,451
305
135
1,035
231
1,750
91
160
92
3,100
825
361
$1,421
—
—
—
11
—
—
—
—
—
—
—
14
1,446
27
—
7
121
827
—
160
11
—
—
52
Southern
Company
Gas
$ 1,428
148
—
—
57
144
—
15
—
—
—
—
82
1,874
93
—
77
—
—
91
—
—
—
—
5
268
561
8,914
(207)
8,707
$ 8,744
237
193
2,164
—
2,164
$3,573
19
153
4,019
(73)
3,946
$3,019
12
34
393
(41)
352
$ 346
—
53
1,258
(27)
1,231
$ 215
—
62
328
(9)
319
$ 1,555
$ (118)
$ 8,862
$ — $ —
$3,019
$3,573
$ (118)
$ 464
$ —
$ 215
$ —
$ 1,555
151
Southern Company 2021 Annual Report Notes to Financial Statements
Deferred tax liabilities —
Accelerated depreciation
Property basis differences
Federal effect of net state deferred tax assets
Leveraged lease basis differences
Employee benefit obligations
Regulatory assets –
Storm damage reserves
Employee benefit obligations
Remaining book value of retired assets
Premium on reacquired debt
AROs
AROs
Other
Total deferred income tax liabilities
Deferred tax assets —
Federal effect of net state deferred tax liabilities
State effect of federal deferred taxes
Employee benefit obligations
Other property basis differences
ITC and PTC carryforward
Long-term debt fair value adjustment
Other partnership basis difference
Other comprehensive losses
AROs
Estimated loss on plants under construction
Other deferred state tax attributes
Regulatory liability associated with the Tax Reform Legislation
December 31, 2020
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$ 8,950
1,999
—
142
739
80
1,313
270
78
1,969
804
437
16,781
284
126
1,511
223
1,853
86
166
128
2,773
369
357
$2,453
1,010
—
—
250
$ 3,228
689
—
—
362
$ 319
148
25
—
39
$1,389
—
—
—
12
—
348
123
12
764
328
128
5,416
151
126
369
—
12
—
—
7
1,092
—
—
80
438
141
66
1,165
429
82
6,680
59
—
522
72
539
—
—
17
1,594
369
9
—
62
6
—
40
—
66
705
—
—
80
—
—
—
—
—
40
—
250
—
—
—
—
—
—
12
1,413
26
—
6
134
1,110
—
166
25
—
—
68
Southern
Company
Gas
$ 1,349
135
—
—
26
—
45
—
—
—
—
138
1,693
70
—
100
—
—
86
—
—
—
—
10
(not subject to normalization)
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
338
660
8,874
(136)
8,738
$ 8,043
243
143
2,143
—
2,143
$3,273
76
186
3,443
(35)
3,408
$3,272
19
39
428
(41)
387
$ 318
—
52
1,587
(35)
1,552
$ (139)
—
166
432
(4)
428
$ 1,265
$ (132)
$ 8,175
$ —
$3,273
$ —
$3,272
$ (129)
$ 447
$ (262)
$ 123
$ —
$ 1,265
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, 2021
and 2020.
152
Southern Company 2021 Annual Report Notes to Financial Statements
Tax Credit Carryforwards
Federal ITC/PTC carryforwards at December 31, 2021 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
$1,218
2031
2024
(in millions)
$
12
2032
2024
$ 173
2031
2024
$ 827
2035
2024
The estimated tax credit utilization reflects the various sale transactions described in Note 15 and could be further delayed by numerous
factors, including the acquisition of additional renewable projects, an increase in Georgia Power’s ownership interest percentage in
Plant Vogtle Units 3 and 4, the purchase of rights to additional PTCs of Plant Vogtle Units 3 and 4 pursuant to certain joint ownership
agreements, changes in taxable income projections, and potential income tax rate changes. See Note 2 under “Georgia Power – Nuclear
Construction” for additional information on Plant Vogtle Units 3 and 4.
At December 31, 2021, Georgia Power also had approximately $428 million in net state investment and other net state tax credit
carryforwards for the State of Georgia that will expire between tax years 2021 and 2031 and are not expected to be fully utilized.
Georgia Power has a net state valuation allowance of $58 million associated with these carryforwards.
The ultimate outcome of these matters cannot be determined at this time.
Net Operating Loss Carryforwards
At December 31, 2021, 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
South Carolina
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
$195
2031
27
10
2
2
$ 41
11
14
17
$278
2035
2034
2036
Various
2035
2035
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, 2021.
State NOLs for Mississippi, Oklahoma, and Florida are not expected to be fully utilized prior to expiration. At December 31, 2021,
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.
153
Southern Company 2021 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, 2018 and 2019
Tax positions changes – increase from prior periods
Unrecognized tax benefits at December 31, 2020
Tax positions changes – increase from prior periods
Unrecognized tax benefits at December 31, 2021
Southern Company
(in millions)
$ —
44
44
3
$47
The unrecognized tax positions increase from prior periods for 2020 and the balance of unrecognized tax benefits at December 31, 2020 and
2021 primarily relate to a 2019 state tax filing position to exclude certain gains from 2019 dispositions from taxation in a certain unitary state.
If accepted by the state, this position would decrease Southern Company’s annual effective tax rate. The ultimate outcome of this unrecognized
tax benefit is dependent on completion of the related state audit, which is not expected to be resolved within the next 12 months.
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 2020. Southern Company is a
participant in the Compliance Assurance Process of the IRS. 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, 2021 and no mandatory contributions to the qualified pension plan are anticipated for the year ending December 31, 2022. The
Southern Company system also provides certain non-qualified defined benefits for a select group of management and highly compensated
employees, which are funded on a cash basis. In addition, the Southern Company system provides certain medical care and life insurance
benefits for retired employees through other postretirement benefit plans. The traditional electric operating companies fund other
postretirement trusts to the extent required by their respective regulatory commissions. Southern Company Gas has a separate unfunded
supplemental retirement health care plan that provides medical care and life insurance benefits to employees of discontinued businesses.
For the year ending December 31, 2022, no contributions to any other postretirement trusts are expected.
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
2021
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
154
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
2.75%
2.10
2.97
8.25
4.80
2.46%
1.64
3.01
6.54
4.80
Southern Company 2021 Annual Report Notes to Financial Statements
Assumptions used to determine net periodic costs:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
2020
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
3.41 %
2.99
3.66
8.25
4.73
3.24 %
2.80
3.57
7.25
4.73
3.44%
3.01
3.69
8.25
4.73
3.28%
2.84
3.61
7.36
4.73
3.40%
2.96
3.67
8.25
4.73
3.22%
2.79
3.57
7.05
4.73
3.41%
2.99
3.67
8.25
4.73
3.22%
2.76
3.57
7.07
4.73
3.52 %
3.18
3.70
8.25
4.73
3.39 %
2.97
3.57
—
4.73
2019
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
4.49 %
4.12
4.70
7.75
4.34
4.37 %
3.98
4.63
6.86
4.34
4.51%
4.14
4.73
7.75
4.46
4.40%
4.01
4.67
6.76
4.46
4.48%
4.10
4.72
7.75
4.46
4.36%
3.97
4.64
6.85
4.46
4.49%
4.12
4.73
7.75
4.46
4.35%
3.95
4.64
6.79
4.46
4.65 %
4.35
4.75
7.75
4.46
4.50 %
4.14
4.65
—
4.46
2021
Assumptions used to determine benefit obligations:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company
Gas
3.39%
2.99
3.53
8.25
4.73
3.19%
2.71
3.52
6.69
4.73
Southern
Company
Gas
4.47%
4.11
4.57
7.75
3.07
4.32%
3.91
4.56
6.49
3.07
Southern
Company
Gas
Pension plans
Discount rate
Annual salary increase
Other postretirement benefit plans
Discount rate
Annual salary increase
3.09%
4.80
2.90%
4.80
3.12%
4.80
2.95%
4.80
3.07%
4.80
2.87%
4.80
3.07%
4.80
2.88%
4.80
3.21%
4.80
3.07%
4.80
3.04%
4.80
2.82%
4.80
2020
Assumptions used to determine benefit obligations:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Pension plans
Discount rate
Annual salary increase
Other postretirement benefit plans
Discount rate
Annual salary increase
2.81 %
4.80
2.56 %
4.80
2.85%
4.80
2.63%
4.80
2.79%
4.80
2.52%
4.80
2.80%
4.80
2.53%
4.80
2.99 %
4.80
2.78 %
4.80
Southern
Company
Gas
2.75%
4.80
2.46%
4.80
155
Southern Company 2021 Annual Report Notes to Financial Statements
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. Prior to 2020, the Registrants set the expected rate of return assumption using asset return modeling based on
geometric returns that reflect the compound average returns for dependent annual periods. Beginning in 2020, 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, 2021 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
6.00%
5.00
6.25
4.50%
4.50
4.50
2028
2028
2029
The total accumulated benefit obligation for the pension plans at December 31, 2021 and 2020 was as follows:
December 31, 2021
December 31, 2020
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
Southern
Company
Gas
$14,687
14,922
$3,362
3,414
$4,562
4,657
$672
683
$178
175
$1,030
1,072
An actuarial gain of $393 million was recorded for the annual remeasurement of the Southern Company system pension plans at
December 31, 2021 primarily due to an increase of 28 basis points in the overall discount rate used to calculate the benefit obligation
as a result of higher market interest rates. An actuarial loss of $1.7 billion was recorded for the annual remeasurement of the Southern
Company system pension plans at December 31, 2020 primarily due to a decrease of 60 basis points in the overall discount rate used to
calculate the benefit obligation as a result of lower market interest rates.
Changes in the projected benefit obligations and the fair value of plan assets during the plan years ended December 31, 2021 and 2020
were as follows:
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 return on plan assets
Employer contributions
Benefits paid
Fair value of plan assets at end of year
Accrued asset (liability)
156
2021
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$16,646
434
346
(651)
(393)
16,382
15,367
2,449
60
(651)
17,225
843
$
$ 3,854
102
82
(137)
(95)
3,806
3,684
586
8
(137)
4,141
$ 335
$5,127
112
104
(210)
(121)
5,012
4,844
781
—
(210)
5,415
$ 403
$754
18
16
(28)
(17)
743
701
111
2
(28)
786
$ 43
$217
10
5
(4)
(6)
222
186
30
1
(4)
213
$ (9)
Southern
Company
Gas
$1,189
37
24
(73)
(43)
1,134
1,123
181
10
(73)
1,241
$ 107
Southern Company 2021 Annual Report Notes to Financial Statements
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 liability
2020
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$14,788
376
432
(629)
1,679
16,646
14,057
1,881
58
(629)
15,367
$ (1,279)
$3,404
89
100
(132)
393
3,854
3,357
450
9
(132)
3,684
$ (170)
$4,610
96
133
(202)
490
5,127
4,442
594
10
(202)
4,844
$ (283)
$671
15
20
(27)
75
754
641
85
2
(27)
701
$ (53)
$ 185
8
6
(6)
24
217
169
22
1
(6)
186
$ (31)
Southern
Company
Gas
$ 1,067
33
31
(69)
127
1,189
1,050
139
3
(69)
1,123
$ (66)
The projected benefit obligations for the qualified and non-qualified pension plans at December 31, 2021 are shown in the following table.
All pension plan assets are related to the qualified pension plan.
Projected benefit obligations:
Qualified pension plan
Non-qualified pension plan
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
Southern
Company
Gas
$15,568
814
$3,678
129
$4,852
160
$708
36
$193
29
$1,066
68
Amounts recognized in the balance sheets at December 31, 2021 and 2020 related to the Registrants’ pension plans consist of the following:
December 31, 2021:
Prepaid pension costs(a)
Other regulatory assets, deferred(b)
Other current liabilities
Employee benefit obligations(c)
Other regulatory liabilities, deferred
AOCI
December 31, 2020:
Prepaid pension costs
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)
$ 1,657
2,920
(55)
(759)
(119)
100
$ —
4,655
(52)
(1,227)
(34)
245
$ 464
809
(9)
(120)
—
—
$ 563
971
(12)
(148)
—
—
$ — $ —
1,598
(10)
(273)
—
—
1,286
(9)
(161)
—
—
$ 78
146
(2)
(33)
—
—
$ —
235
(2)
(51)
—
—
$ 20
—
(2)
(27)
—
35
$ —
—
(2)
(29)
—
60
Southern
Company
Gas
$ 175
91
(2)
(66)
—
(45)
$ 70
205
(2)
(134)
—
1
(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 $210 million and $224 million at December 31, 2021 and 2020, 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.
157
Southern Company 2021 Annual Report Notes to Financial Statements
Presented below are the amounts included in regulatory assets at December 31, 2021 and 2020 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, 2021
Regulatory assets:
Prior service cost
Net loss
Regulatory amortization
Total regulatory assets(*)
Balance at December 31, 2020
Regulatory assets:
Prior service cost
Net loss
Regulatory amortization
Total regulatory assets(*)
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
(in millions)
$
11
2,790
—
$ 2,801
$
5
804
—
$ 809
$
8
963
—
$ 971
$
11
4,610
—
$ 4,621
$
5
1,281
—
$ 1,286
$
9
1,589
—
$1,598
$
1
145
—
$ 146
$
2
233
—
$ 235
Southern
Company
Gas
$ (11)
38
64
91
$
$ (13)
135
83
$ 205
(*) Amounts for Southern Company exclude regulatory assets of $210 million and $224 million at December 31, 2021 and 2020, respectively, associated with
unamortized amounts in Southern Company Gas’ pension plans prior to its acquisition by Southern Company.
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, 2021 and 2020 are
Notes to Financial Statements
presented in the following table:
Presented below are the amounts included in regulatory assets at December 31, 2021 and 2020 related to the portion of the defined
Southern
Company
Gas
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.
Regulatory assets (liabilities):(*)
Balance at December 31, 2019
Net loss
Reclassification adjustments:
Mississippi
Power
Southern
Company
Alabama
Power
Georgia
Power
(in millions)
Balance at December 31, 2021
Amortization of prior service costs
Amortization of net loss
Amortization of regulatory assets(*)
Regulatory assets:
Prior service cost
Total reclassification adjustments
Net loss
Total change
Regulatory amortization
Balance at December 31, 2020
Total regulatory assets(*)
Net gain
Reclassification adjustments:
Balance at December 31, 2020
Amortization of prior service costs
Regulatory assets:
Amortization of net loss
Amortization of regulatory assets(*)
Prior service cost
Net loss
Total reclassification adjustments
Regulatory amortization
Total change
Balance at December 31, 2021
Total regulatory assets(*)
$ 3,993
884
Southern
Company
(1)
(255)
—
11
(256)
2,790
628
—
$ 4,621
$ 2,801
(1,523)
$
$1,130
228
Alabama
Power
(1)
(71)
—
5
(72)
804
156
—
$1,286
$ 809
(394)
$
(in millions)
$1,416
269
Georgia
Power
(1)
(86)
—
8
(87)
963
182
—
$1,598
$ 971
(527)
$
$ 203
45
Mississippi
Power
—
(13)
—
1
(13)
145
32
—
$ 235
$ 146
(74)
$
$ 172
Southern
45
Company
Gas
2
(8)
(6)
$ (11)
(12)
38
33
64
$ 205
91
$
(97)
$
(1)
(296)
11
—
4,610
(297)
—
(1,820)
$ 4,621
$ 2,801
$
(1)
(82)
5
—
1,281
(83)
—
(477)
$ 1,286
$ 809
$
(1)
(99)
9
—
1,589
(100)
—
(627)
$1,598
$ 971
$
—
(15)
2
—
233
(15)
—
(89)
$ 235
$ 146
2
(9)
$ (13)
(10)
135
(17)
83
(114)
$ 205
$ 91
(*) Amounts for Southern Company exclude regulatory assets of $210 million and $224 million at December 31, 2021 and 2020, respectively, associated with
(*) Amounts for Southern Company exclude regulatory assets of $210 million and $224 million at December 31, 2021 and 2020, respectively, associated with
unamortized amounts in Southern Company Gas’ pension plans prior to its acquisition by Southern Company.
unamortized amounts in Southern Company Gas’ pension plans prior to its acquisition by Southern Company.
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, 2021 and 2020 are
presented in the following table:
158 Southern Company 2021 Annual Report
Regulatory assets (liabilities):(*)
Balance at December 31, 2019
Net loss
Reclassification adjustments:
workings.indd 1
workings.indd 1
Amortization of prior service costs
Amortization of net loss
Amortization of regulatory assets(*)
Total reclassification adjustments
Balance at December 31, 2020
Total change
Net gain
Reclassification adjustments:
Amortization of prior service costs
Amortization of net loss
Amortization of regulatory assets(*)
Total reclassification adjustments
Total change
Balance at December 31, 2021
158 Southern Company 2021 Annual Report
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
(in millions)
Southern
Company
Gas
$ 3,993
884
$1,130
228
$1,416
269
$ 203
45
$ 172
45
3/23/22 12:21 PM
3/23/22 12:21 PM
$ 4,621
$1,286
$1,598
(1,523)
(394)
(527)
$ 235
(74)
$ 205
(97)
(1)
(255)
—
(256)
628
(1)
(296)
—
(297)
(1,820)
(1)
(71)
—
(72)
156
(1)
(82)
—
(83)
(477)
(1)
(86)
—
(87)
182
(1)
(99)
—
(100)
(627)
—
(13)
—
(13)
32
—
(15)
—
(15)
(89)
2
(8)
(6)
(12)
33
2
(9)
(10)
(17)
(114)
$ 91
$ 2,801
$ 809
$ 971
$ 146
(*) Amounts for Southern Company exclude regulatory assets of $210 million and $224 million at December 31, 2021 and 2020, respectively, associated with
unamortized amounts in Southern Company Gas’ pension plans prior to its acquisition by Southern Company.
Notes to Financial Statements
Presented below are the amounts included in AOCI at December 31, 2021 and 2020 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.
Balance at December 31, 2021
AOCI:
Prior service cost
Net (gain) loss
Total AOCI
Balance at December 31, 2020
AOCI:
Prior service cost
Net loss
Total AOCI
Southern
Company
Southern
Power
(in millions)
Southern
Company
Gas
$ (2)
102
$ 100
$ (3)
248
$ 245
$ —
35
$35
$ —
60
$60
$ (3)
(42)
$ (45)
$ (4)
5
$ 1
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, 2021 and 2020 are presented in the following table:
Southern
Company
Southern
Power
(in millions)
Southern
Company
Gas
AOCI:
Balance at December 31, 2019
Net loss
Reclassification adjustments:
Amortization of prior service costs
Amortization of net loss
Total reclassification adjustments
Total change
Balance at December 31, 2020
Net gain
Reclassification adjustments:
Amortization of net gain (loss)
Total reclassification adjustments
Total change
Balance at December 31, 2021
$ 185
74
—
(14)
(14)
60
$ 245
(128)
(17)
(17)
(145)
$ 100
$ 46
16
—
(2)
(2)
14
$ 60
(22)
(3)
(3)
(25)
$ 35
$(14)
15
1
(1)
—
15
$ 1
(47)
1
1
(46)
$(45)
159
Southern Company 2021 Annual Report Notes to Financial Statements
Components of net periodic pension cost for the Registrants were as follows:
2021
Service cost
Interest cost
Expected return on plan assets
Recognized net loss
Net amortization
Prior service cost
Net periodic pension cost (income)
2020
Service cost
Interest cost
Expected return on plan assets
Recognized net loss
Net amortization
Prior service cost
Net periodic pension cost (income)
2019
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
$
$
$
$
$
$
434
346
(1,191)
314
1
—
(96)
376
432
(1,100)
269
1
—
(22)
292
492
(885)
120
2
—
21
$ 102
82
(287)
82
1
—
$ (20)
$ 89
100
(264)
71
1
—
$ (3)
$ 69
114
(206)
37
—
—
$ 14
$ 112
104
(375)
100
1
—
$ (58)
$ 96
133
(347)
86
1
—
$ (31)
$ 74
156
(292)
44
1
—
$ (17)
$ 18
16
(55)
15
—
—
$ (6)
$ 15
20
(51)
13
—
—
$ (3)
$ 12
22
(40)
6
—
—
$ —
$ 10
5
(14)
3
—
—
$ 4
$ 8
6
(13)
2
—
—
$ 3
$ 7
5
(10)
1
—
—
$ 3
$ 37
24
(86)
13
15
(3)
$ —
$ 33
31
(75)
6
15
(3)
$ 7
$ 25
36
(60)
2
14
(3)
$ 14
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.
Effective January 1, 2020, Southern Company changed its method of calculating the market-related value of the liability-hedging securities
included in its pension plan assets. The market-related value is used to determine the expected return on plan assets component of net
periodic pension cost. Southern Company previously used the calculated value approach for all plan assets, which smoothed asset returns
and deferred gains and losses by amortizing them into the calculation of the market-related value over five years. Southern Company
changed to the fair value approach for liability-hedging securities, which includes measuring the market-related value of that portion of
the plan assets at fair value for purposes of determining the expected return on plan assets. The remaining asset classes of plan assets
continue to be valued using the calculated value approach. Southern Company considers the fair value approach to be preferable for
liability-hedging securities because it results in a current reflection of changes in the value of plan assets in the measurement of net
periodic pension cost more consistent with the change in the related obligations.
160
Southern Company 2021 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, 2021, estimated benefit payments were as follows:
Benefit Payments:
2022
2023
2024
2025
2026
2027 to 2031
Other Postretirement Benefits
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$ 690
714
736
759
780
4,138
$148
155
159
165
171
921
$ 223
229
235
240
245
1,275
$ 31
31
32
34
35
187
$ 6
6
6
7
7
42
Southern
Company
Gas
$ 65
65
64
64
64
329
Changes in the APBO and the fair value of the Registrants’ plan assets during the plan years ended December 31, 2021 and 2020 were as follows:
Change in benefit obligation
Benefit obligation at beginning of year
Service cost
Interest cost
Benefits paid
Actuarial (gain) loss
Retiree drug subsidy
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) loss
Retiree drug subsidy
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 liability
2021
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$1,948
24
35
(105)
(54)
1
1,849
1,158
154
43
(104)
1,251
$ (598)
$ 463
6
9
(22)
(16)
—
440
458
55
(2)
(22)
489
$ 49
$ 699
7
12
(36)
(26)
—
656
427
55
4
(36)
450
$(206)
$ 81
1
1
(5)
(2)
—
76
27
4
3
(5)
29
$(47)
$ 12
—
—
—
(1)
—
11
—
—
—
—
—
$(11)
2020
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$ 1,985
22
54
(126)
7
6
1,948
1,061
145
72
(120)
1,158
$ (790)
$ 462
6
13
(29)
9
2
463
413
60
12
(27)
458
$ (5)
$ 742
6
20
(46)
(26)
3
699
403
50
17
(43)
427
$(272)
$ 87
1
2
(6)
(3)
—
81
26
3
4
(6)
27
$ (54)
$ 11
1
—
—
—
—
12
—
—
—
—
—
$(12)
Southern
Company
Gas
$ 248
2
4
(18)
1
—
237
128
18
15
(18)
143
$ (94)
Southern
Company
Gas
$ 250
2
7
(17)
6
—
248
115
18
12
(17)
128
$(120)
161
Southern Company 2021 Annual Report Notes to Financial Statements
Amounts recognized in the balance sheets at December 31, 2021 and 2020 related to the Registrants’ other postretirement benefit plans
consist of the following:
December 31, 2021:
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, 2020:
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)
$ —
97
(5)
(593)
(171)
—
$ 137
(5)
(785)
(86)
8
$ 49
—
—
—
(62)
—
$ —
—
(5)
(21)
—
$ —
30
—
(206)
(40)
—
$ 47
—
(272)
—
—
$ —
2
—
(47)
(1)
—
$ 5
—
(54)
—
—
$ —
—
—
(11)
—
2
$ —
—
(12)
—
3
Southern
Company
Gas
$ —
—
—
(94)
(34)
(5)
$ (23)
—
(120)
—
—
(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 $40 million and $47 million at December 31, 2021 and 2020, 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, 2021 and 2020 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, 2021:
Regulatory assets (liabilities):
Prior service cost
Net gain
Regulatory amortization
Total regulatory assets (liabilities)(*)
Balance at December 31, 2020:
Regulatory assets (liabilities):
Prior service cost
Net (gain) loss
Regulatory amortization
Total regulatory assets (liabilities)(*)
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
(in millions)
Southern
Company
Gas
$ 13
(87)
—
$(74)
$ 12
39
—
$ 51
$ 3
(65)
—
$(62)
$ 3
(24)
—
$ (21)
$ 5
(15)
—
$(10)
$ 5
42
—
$ 47
$ 1
—
—
$ 1
$—
5
—
$ 5
$ 1
(51)
16
$(34)
$ 1
(49)
25
$(23)
(*) Amounts for Southern Company exclude regulatory assets of $40 million and $47 million at December 31, 2021 and 2020, respectively, associated with
unamortized amounts in Southern Company Gas’ other postretirement benefit plans prior to its acquisition by Southern Company.
162
Southern Company 2021 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, 2021 and 2020 are presented in the following table:
Net regulatory assets (liabilities):(*)
Balance at December 31, 2019
Net gain
Reclassification adjustments:
Amortization of prior service costs
Amortization of net loss
Amortization of regulatory assets(*)
Total reclassification adjustments
Total change
Balance at December 31, 2020
Net gain
Reclassification adjustments:
Amortization of prior service costs
Amortization of net loss
Amortization of regulatory assets(*)
Total reclassification adjustments
Total change
Balance at December 31, 2021
Southern
Company
Alabama
Power
Georgia
Power
(in millions)
Mississippi
Power
Southern
Company
Gas
$ 121
(65)
1
(6)
—
(5)
(70)
$ 51
(120)
1
(6)
—
(5)
(125)
$ (74)
$ 1
(22)
—
—
—
—
(22)
$ (21)
(41)
—
—
—
—
(41)
$ (62)
$ 96
(47)
1
(3)
—
(2)
(49)
$ 47
(55)
1
(3)
—
(2)
(57)
$(10)
$ 10
(5)
—
—
—
—
(5)
$ 5
(4)
—
—
—
—
(4)
$ 1
$ (11)
(5)
—
—
(7)
(7)
(12)
$ (23)
(2)
—
—
(9)
(9)
(11)
$ (34)
(*) Amounts for Southern Company exclude regulatory assets of $40 million and $47 million at December 31, 2021 and 2020, 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, 2021 and 2020 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.
Balance at December 31, 2021
AOCI:
Prior service cost
Net (gain) loss
Total AOCI
Balance at December 31, 2020
AOCI:
Prior service cost
Net (gain) loss
Total AOCI
Southern
Company
Southern
Power
(in millions)
Southern
Company
Gas
$
1
(1)
$ —
$
$
1
7
8
$ —
2
$ 2
$ —
3
$ 3
$ 1
(6)
$ (5)
$ 1
(1)
$ —
163
Southern Company 2021 Annual Report Notes to Financial Statements
The components of OCI related to the other postretirement benefit plans for the plan years ended December 31, 2021 and 2020 are
presented in the following table:
AOCI:
Balance at December 31, 2019
Net loss
Reclassification adjustments:
Amortization of net gain (loss)
Total change
Balance at December 31, 2020
Net gain
Reclassification adjustments:
Amortization of net gain (loss)
Total change
Balance at December 31, 2021
Southern
Company
Southern
Power
(in millions)
Southern
Company
Gas
$ 2
2
4
6
$ 8
(11)
3
(8)
$ —
$ 2
1
—
1
$ 3
(1)
—
(1)
$ 2
$ (4)
—
4
4
$ —
—
(5)
(5)
$ (5)
Components of the other postretirement benefit plans’ net periodic cost for the Registrants were as follows:
2021
Service cost
Interest cost
Expected return on plan assets
Net amortization
Net periodic postretirement benefit cost (income)
2020
Service cost
Interest cost
Expected return on plan assets
Net amortization
Net periodic postretirement benefit cost (income)
2019
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)
Southern
Company
Gas
$ 24
35
(76)
2
$(15)
$ 22
54
(72)
1
$ 5
$ 18
69
(65)
—
$ 22
$
6
9
(30)
—
$ (15)
$
6
13
(29)
—
$(10)
$
5
16
(26)
4
$ (1)
$ 7
12
(26)
2
$ (5)
$ 6
20
(26)
2
$ 2
$ 5
26
(25)
1
$ 7
$ 1
1
(1)
—
$ 1
$ 1
2
(1)
—
$ 2
$ 1
3
(2)
—
$ 2
$ —
—
1
—
$ 1
$ 1
—
—
—
$ 1
$ 1
—
—
—
$ 1
$ 2
4
(10)
6
$ 2
$ 2
7
(10)
6
$ 5
$ 1
9
(7)
6
$ 9
164
Southern Company 2021 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:
2022
2023
2024
2025
2026
2027 to 2031
Benefit Plan Assets
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$ 111
110
109
112
112
552
$
24
24
24
25
25
128
$ 40
39
38
40
40
199
$ 5
5
5
5
5
22
$ —
—
—
1
1
3
Southern
Company
Gas
$ 17
17
18
17
17
75
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.
Southern Company’s investment strategy also includes adjusting the established asset allocation to invest a larger portion of the portfolio
in fixed rate debt securities should the qualified pension plan achieve a predetermined funding threshold. Any future reallocation of plan
assets based on achieving the funding threshold would likely result in a reduction in the expected long-term return on plan assets used
to determine pension income. However, the amount of such a decrease and the related financial statement impact cannot be determined
at this time.
165
Southern Company 2021 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 growth attributes,
Domestic and international equities such as common stocks,
American depositary receipts, and real estate investment trusts that
managed both actively and through passive index approaches.
trade on public exchanges are classified as Level 1 investments and
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
Trust-owned life insurance (TOLI): Investments of taxable trusts
aimed at minimizing the impact of taxes on the portfolio.
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.
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.
Special situations: Investments in opportunistic strategies with
the objective of diversifying and enhancing returns and exploiting
Investments in real estate, private equity, and special situations
are generally classified as Net Asset Value as a Practical Expedient,
short-term inefficiencies, as well as investments in promising new
since the underlying assets typically do not have publicly available
strategies of a longer-term nature.
Real estate: Investments in traditional private market, equity-
oriented investments in real properties (indirectly through pooled
funds or partnerships) and in publicly traded real estate securities.
observable inputs. The fund manager values 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
Private equity: Investments in private partnerships that invest in
private or public securities typically through privately-negotiated
capitalization rates, recent sales of comparable investments, and
independent third-party appraisals. The fair value of partnerships
and/or structured transactions, including leveraged buyouts,
is determined by aggregating the value of the underlying assets
venture capital, and distressed debt.
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. The Registrants did not have
any investments classified as Level 3 at December 31, 2020.
166
Southern Company 2021 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,
2021 and 2020 are presented below.
At December 31, 2021:
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
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
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
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)
Net Asset
Value as a
Practical
Expedient
(NAV)
(in millions)
Target
Allocation
Actual
Allocation
Total
$3,095
2,740
$ 1,326
1,402
$ — $ — $ 4,421
— 4,145
3
—
—
—
—
405
706
—
—
$6,946
1,209
10
1,752
771
7
—
—
—
$ 6,477
$ 743
659
$ 319
337
—
—
—
—
97
170
—
—
$1,669
291
2
421
186
2
—
—
—
$ 1,558
—
—
—
—
—
—
—
—
$ 3
— 1,209
—
10
— 1,752
771
—
412
—
2,744
2,038
171
171
1,590
1,590
$3,799 $17,225
$ — $ — $ 1,062
997
—
1
—
—
—
—
—
—
—
—
$ 1
—
—
—
—
—
490
41
382
291
2
421
186
99
660
41
382
$ 913 $ 4,141
$ 972
861
$ 417
441
$ — $ — $ 1,389
— 1,303
1
—
—
—
—
127
222
—
—
$2,182
380
3
551
243
2
—
—
—
$ 2,037
—
—
—
—
—
—
—
—
$ 1
—
—
—
—
—
641
54
500
380
3
551
243
129
863
54
500
$1,195 $ 5,415
51%
53%
23
22
14
3
9
100%
15
1
9
100%
51%
53%
23
22
14
3
9
100%
15
1
9
100%
51%
53%
23
22
14
3
9
100%
15
1
9
100%
167
Southern Company 2021 Annual Report Notes to Financial Statements
At December 31, 2021:
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 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
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Total
168
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)
Net Asset
Value as a
Practical
Expedient
(NAV)
(in millions)
Target
Allocation
Actual
Allocation
Total
$142
126
—
—
—
18
32
—
—
$318
$ 38
34
—
—
—
5
9
—
—
$ 86
$223
197
—
—
—
—
29
51
—
—
$500
$ 61
64
55
80
35
—
—
—
—
$295
$ 16
17
15
22
10
—
—
—
—
$ 80
$ 96
101
87
1
126
56
—
—
—
—
$467
$ —
—
—
—
—
—
—
—
—
$ —
$ —
—
—
—
—
—
—
—
—
$ —
$ —
—
—
—
—
—
—
—
—
—
$ —
$ — $ 203
190
—
—
—
—
—
93
8
73
$174
55
80
35
18
125
8
73
$ 787
$ — $ 54
51
—
—
—
—
—
25
2
20
$ 47
15
22
10
5
34
2
20
$ 213
$ — $ 319
298
—
—
—
—
—
—
147
12
115
$274
87
1
126
56
29
198
12
115
$1,241
51%
53%
23
22
14
3
9
100%
15
1
9
100%
51%
53%
23
22
14
3
9
100%
15
1
9
100%
51%
53%
23
22
14
3
9
100%
15
1
9
100%
Southern Company 2021 Annual Report Notes to Financial Statements
At December 31, 2020:
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
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
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
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
$2,852
2,660
—
—
—
—
356
542
—
—
$6,410
$ 685
638
—
—
—
—
85
130
—
—
$1,538
$ 899
839
—
—
—
—
112
171
—
—
$2,021
$1,247
1,497
951
9
1,673
772
5
—
—
—
$6,154
$ 299
359
228
2
401
185
1
—
—
—
$1,475
$ 393
472
300
3
527
243
1
—
—
—
$1,939
$ — $ 4,099
4,157
—
—
—
—
—
—
1,596
166
1,104
$2,866
951
9
1,673
772
361
2,138
166
1,104
$15,430
$ — $
—
984
997
—
—
—
—
—
382
40
264
$ 686
228
2
401
185
86
512
40
264
$ 3,699
$ — $ 1,292
1,311
—
—
—
—
—
—
503
53
348
$ 904
300
3
527
243
113
674
53
348
$ 4,864
51%
56%
23
23
14
3
9
100%
13
1
7
100%
51%
56%
23
23
14
3
9
100%
13
1
7
100%
51%
56%
23
23
14
3
9
100%
13
1
7
100%
169
Southern Company 2021 Annual Report Notes to Financial Statements
At December 31, 2020:
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 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
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Total
170
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
$131
122
—
—
—
16
25
—
—
$294
$ 35
32
—
—
—
4
7
—
—
$ 78
$209
195
—
—
—
—
26
40
—
—
$470
$ 57
68
43
76
35
—
—
—
—
$279
$ 15
19
12
20
9
—
—
—
—
$ 75
$ 91
109
69
1
122
56
—
—
—
—
$448
$ —
—
—
—
—
—
73
8
50
$131
$ —
—
—
—
—
—
19
2
13
$ 34
$ —
—
—
—
—
—
—
117
12
81
$210
$ 188
190
43
76
35
16
98
8
50
$ 704
$ 50
51
12
20
9
4
26
2
13
$ 187
$ 300
304
69
1
122
56
26
157
12
81
$1,128
51%
56%
23
23
14
3
9
100%
13
1
7
100%
51%
56%
23
23
14
3
9
100%
13
1
7
100%
51%
56%
23
23
14
3
9
100%
13
1
7
100%
Southern Company 2021 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, 2021 and 2020 are presented below.
At December 31, 2021:
Southern Company
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
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
$123
73
—
—
—
14
—
20
—
—
$230
$ 26
23
—
—
—
3
—
6
—
—
$ 58
$ 65
22
—
—
—
5
—
7
—
—
$ 99
$112
99
37
50
90
—
530
—
—
—
$918
$ 11
12
10
18
6
—
341
—
—
—
$398
$ 13
50
9
14
46
—
189
—
—
—
$321
$ —
—
—
—
—
—
—
54
5
42
$101
$ —
—
—
—
—
—
—
17
2
13
$ 32
$ —
—
—
—
—
—
—
16
1
13
$ 30
$ 235
172
37
50
90
14
530
74
5
42
$ 1,249
$
37
35
10
18
6
3
341
23
2
13
$ 488
$
78
72
9
14
46
5
189
23
1
13
$ 450
64%
66%
27
25
5
1
3
100%
6
—
3
100%
71%
69%
21
21
4
1
3
100%
7
—
3
100%
60%
62%
33
30
4
1
2
100%
5
—
3
100%
171
Southern Company 2021 Annual Report Notes to Financial Statements
At December 31, 2021:
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
$ 4
4
—
—
—
1
1
—
—
$10
$ 3
2
—
—
—
2
1
—
$ 8
$
2
2
5
2
1
—
—
—
—
$ 12
$ 76
24
1
1
30
—
—
—
$132
$—
—
—
—
—
—
3
—
2
$ 5
$—
—
—
—
—
—
2
1
$ 3
$ 6
6
5
2
1
1
4
—
2
$ 27
$ 79
26
1
1
30
2
3
1
$143
43%
44%
36
34
11
2
8
100%
13
1
8
100%
72%
73%
26
24
1
1
100%
2
1
100%
172
Southern Company 2021 Annual Report Notes to Financial Statements
At December 31, 2020:
Southern Company
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
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
$113
71
—
—
—
15
—
15
—
—
$214
$ 26
23
—
—
—
5
—
5
—
—
$ 59
$ 58
21
—
—
—
5
—
5
—
—
$ 89
$ 98
102
32
44
86
—
508
—
—
—
$ 870
$ 11
13
11
14
7
—
321
—
—
—
$ 377
$ 10
50
8
13
46
—
188
—
—
—
$ 315
$ —
—
—
—
—
—
—
42
4
29
$75
$ —
—
—
—
—
—
—
13
1
9
$23
$ —
—
—
—
—
—
—
13
1
9
$23
$ 211
173
32
44
86
15
508
57
4
29
$ 1,159
$
37
36
11
14
7
5
321
18
1
9
$ 459
$
68
71
8
13
46
5
188
18
1
9
$ 427
63%
66%
28
27
5
1
3
100%
5
—
2
100%
68%
69%
24
25
4
1
3
100%
4
—
2
100%
60%
64%
33
30
4
1
2
100%
4
—
2
100%
173
Southern Company 2021 Annual Report Notes to Financial Statements
At December 31, 2020:
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
$ 4
4
—
—
—
1
1
—
—
$10
$ 2
2
—
—
—
1
—
—
$ 5
$
2
2
5
2
1
—
—
—
—
$ 12
$ 66
25
1
1
25
—
—
—
$ 118
$ —
—
—
—
—
—
2
—
2
$ 4
$ —
—
—
—
—
—
1
1
$ 2
$ 6
6
5
2
1
1
3
—
2
$ 26
$ 68
27
1
1
25
1
1
1
$125
43%
46%
37
36
11
2
7
100%
11
1
6
100%
72%
76%
26
22
1
1
100%
1
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 2021,
2020, and 2019 were as follows:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company
Gas
(in millions)
$119
120
113
$26
26
25
$28
29
27
$5
5
4
$ 2
2
2
$16
16
15
2021
2020
2019
174
Southern Company 2021 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, 2021, the number of current and former employees participating in stock-based compensation programs for the
Registrants was as follows:
Number of employees
Southern
Company
1,728
Alabama
Power
241
Georgia
Power
271
Mississippi
Power
Southern
Power
Southern
Company Gas
70
45
173
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 three 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; ROE awards based on Southern Company’s equity-weighted return over the performance period; and EPS awards
based on Southern Company’s cumulative EPS over the performance period. EPS awards were last granted in 2017.
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
2021
30.0%
3
0.2%
2020
15.4%
3
1.4%
2019
15.6%
3
2.4%
$69.06
$77.65
$62.71
The Registrants recognize TSR award compensation expense on a straight-line basis over the three-year performance period without remeasurement.
The fair values of EPS awards and 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 2021, 2020, and 2019 was $59.49, $68.42, and
$49.38, respectively. Compensation expense for EPS and ROE awards is generally recognized ratably over the three-year performance
period adjusted for expected changes in EPS and ROE performance. Total compensation cost recognized for vested EPS awards and ROE
awards reflects final performance metrics.
Southern Company had 2.2 million unvested PSUs outstanding at December 31, 2020. In February 2021, the PSUs that vested for
the three-year performance period ended December 31, 2020 were converted into 2.5 million shares outstanding at a share price of
$60.10. During 2021, Southern Company granted 1.3 million PSUs and 1.3 million PSUs were vested or forfeited, resulting in 2.2 million
unvested PSUs outstanding at December 31, 2021. In February 2022, the PSUs that vested for the three-year performance period ended
December 31, 2021 were converted into 2.5 million shares outstanding at a weighted average share price of $66.57.
175
Southern Company 2021 Annual Report Notes to Financial Statements
Total PSU compensation cost, and the related tax benefit recognized in income, for the years ended December 31, 2021, 2020, and 2019
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
2021
$112
29
$ 17
4
2020
(in millions)
$84
22
$13
4
2019
$77
20
$14
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, 2021, 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, 2021 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 2021, 2020, and 2019 were $59.56, $67.60, and $50.44, 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 1.2 million RSUs outstanding at December 31, 2020. During 2021, Southern Company granted 0.5 million RSUs and
0.6 million RSUs were vested or forfeited, resulting in 1.1 million unvested RSUs outstanding at December 31, 2021, including RSUs related
to employee retention agreements.
For the years ended December 31, 2021, 2020, and 2019, Southern Company’s total compensation cost for RSUs recognized in income
was $32 million, $29 million, and $28 million, respectively. The related tax benefit also recognized in income was $8 million, $8 million,
and $7 million for the years ended December 31, 2021, 2020, and 2019, respectively. Total unrecognized compensation cost related to
RSUs at December 31, 2021, which is being recognized over a weighted-average period of approximately 16 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, 2021, 2020, and 2019, as well as the total unrecognized compensation cost at December 31, 2021, 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, 2021, the weighted average remaining contractual term for the options outstanding and
exercisable was approximately 19 months.
Southern Company’s activity in the stock option program for 2021 is summarized below:
Outstanding at December 31, 2020
Exercised
Outstanding and Exercisable at December 31, 2021
176
Shares Subject to
Option
Weighted Average
Exercise Price
(in millions)
4.3
1.5
2.8
$43.04
43.21
$42.95
Southern Company 2021 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, 2021, 2020, and 2019 were $66 million, $66 million, and $482 million, respectively.
At December 31, 2021, the aggregate intrinsic value for the options outstanding and exercisable was as follows:
Total intrinsic value for outstanding and exercisable options
$71
$17
$8
The aggregate intrinsic value for the options outstanding and exercisable was immaterial for Alabama Power, Mississippi Power, and
Southern Power at December 31, 2021.
Total intrinsic value of options exercised, and the related tax benefit, for the years ended December 31, 2021, 2020, and 2019 are
Southern
Company
Georgia
Power
(in millions)
Southern
Company
Gas
presented below:
Year Ended December 31
Southern Company
Intrinsic value of options exercised
Tax benefit of options exercised
Alabama Power
Intrinsic value of options exercised
Tax benefit of options exercised
Georgia Power
Intrinsic value of options exercised
Tax benefit of options exercised
2021
2020
(in millions)
$34
7
$ 3
1
$14
3
$38
9
$ 5
1
$ 9
2
2019
$167
35
$ 21
4
$ 30
6
Total intrinsic value of options exercised, and the related tax benefit recognized in income, for the years ended December 31, 2021, 2020,
and 2019 were immaterial for Mississippi Power, Southern Power, and Southern Company Gas.
13. FAIR VALUE MEASUREMENTS
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.
177
Southern Company 2021 Annual Report At December 31, 2021, 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, 2021:
(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:
$
24
—
791
165
—
—
—
1
—
—
2
22
1,160
9
$2,174
$
$
10
—
—
—
—
10
$ 195
19
225
188
314
56
13
522
93
—
—
25
14
35
$1,699
$
36
29
79
—
13
$ 157
$ —
$
55
468
165
—
—
1
—
—
9
839
—
$1,482
216
—
21
1
271
22
—
—
14
35
$ 635
Energy-related derivatives
$ —
$
11
178
$ —
—
—
—
—
—
—
—
—
—
—
—
—
—
$ —
$ —
—
—
14
—
$14
$ —
—
—
—
—
—
—
—
—
—
—
$ —
$ —
$ —
—
—
—
—
—
—
—
—
150
—
—
—
—
$ 150
$ —
—
—
—
—
$ —
$ 219
19
1,016
353
314
56
13
523
93
150
2
47
1,174
44
$4,023
$
46
29
79
14
13
$ 181
$ —
$
55
—
—
—
—
—
—
150
—
—
—
$ 150
684
165
21
1
272
22
150
9
853
35
$2,267
$ —
$
11
Notes to Financial StatementsSouthern Company 2021 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, 2021:
(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
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:
Foreign currency derivatives
Contingent consideration
Other
Total
Southern Company Gas
Assets:
Energy-related derivatives(a)
Interest rate derivatives
Non-qualified deferred compensation trusts:
Domestic equity
Foreign equity
Pooled funds - fixed income
Cash equivalents
Total
Liabilities:
Energy-related derivatives(a)(b)
Interest rate derivatives
Total
$ —
323
—
—
—
—
—
13
$336
$ —
$ —
40
$ 40
$ —
$ —
$ —
—
—
$ —
$ 24
—
—
—
—
2
$ 26
$ 10
—
$ 10
$ 75
1
185
293
55
251
71
25
$ 956
$
8
$ 56
—
$ 56
$
5
$
4
$ 16
—
13
$ 29
$
5
6
8
3
13
—
$ 35
$ 12
5
$ 17
$ —
—
—
—
—
—
—
—
$ —
$ —
$ —
—
$ —
$ —
$ —
$ —
14
—
$14
$ —
—
—
—
—
—
$ —
$ —
—
$ —
$—
—
—
—
—
—
—
—
$—
$—
$—
—
$—
$—
$—
$—
—
—
$—
$—
—
—
—
—
—
$—
$—
—
$—
$
75
324
185
293
55
251
71
38
$1,292
$
8
$
$
$
$
$
$
$
$
$
$
56
40
96
5
4
16
14
13
43
29
6
8
3
13
2
61
22
5
27
(a) Excludes immaterial cash collateral.
(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.
179
Notes to Financial StatementsSouthern Company 2021 Annual Report At December 31, 2020, 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, 2020:
(Level 1)
(Level 2)
(Level 3)
(NAV)
Total
(in millions)
Southern Company
Assets:
Energy-related derivatives(a)
Interest rate derivatives
Foreign currency 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)
Foreign currency derivatives
Contingent consideration
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:
$ 401
—
—
862
85
—
—
—
13
—
—
1
28
575
9
$ 1,974
$ 389
—
—
$ 389
$ 271
20
87
151
253
284
85
17
386
83
—
—
7
9
24
$1,677
$ 204
23
—
$ 227
$ —
$
12
543
85
—
—
13
—
—
7
311
—
$ 959
141
73
21
1
167
29
—
—
9
24
$ 477
Energy-related derivatives
$ —
$
7
180
$32
—
—
—
—
—
—
—
—
—
—
—
—
—
—
$32
$ 4
—
17
$21
$ —
—
—
—
—
—
—
—
—
—
—
$ —
$ —
$ —
—
—
—
—
—
—
—
—
—
76
—
—
—
—
$76
$ —
—
—
$ —
$ —
—
—
—
—
—
—
76
—
—
—
$76
$ —
$ 704
20
87
1,013
338
284
85
17
399
83
76
1
35
584
33
$ 3,759
$ 597
23
17
$ 637
$
12
684
158
21
1
180
29
76
7
320
24
$ 1,512
$
7
Notes to Financial StatementsSouthern Company 2021 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, 2020:
(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
Total
Liabilities:
Energy-related derivatives
Mississippi Power
Assets:
Energy-related derivatives
Cash equivalents
Total
Liabilities:
Energy-related derivatives
Southern Power
Assets:
Energy-related derivatives
Foreign currency derivatives
Total
Liabilities:
Energy-related derivatives
Foreign currency derivatives
Contingent consideration
Total
Southern Company Gas
Assets:
Energy-related derivatives(a)
Non-qualified deferred compensation trusts:
Domestic equity
Foreign equity
Pooled funds - fixed income
Cash equivalents
Total
Liabilities:
Energy-related derivatives(a)(b)
$ —
319
—
—
—
—
—
21
$340
$ —
$ —
21
$ 21
$ —
$ —
—
$ —
$ —
—
—
$ —
$401
—
—
—
1
$402
$389
$ 15
1
177
263
84
219
54
7
$820
$ 13
$
$
$
9
—
9
9
$
2
87
$ 89
$
3
23
—
$ 26
$233
9
3
17
—
$262
$172
$ —
—
—
—
—
—
—
—
$ —
$ —
$ —
—
$ —
$ —
$ —
—
$ —
$ —
—
17
$17
$32
—
—
—
—
$32
$ 4
$ —
—
—
—
—
—
—
—
$ —
$ —
$ —
—
$ —
$ —
$ —
—
$ —
$ —
—
—
$ —
$ —
—
—
—
—
$ —
$ —
(a) Excludes $6 million associated with premiums and certain weather derivatives accounted for based on intrinsic value rather than fair value and cash
collateral of $28 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.
$
15
320
177
263
84
219
54
28
$ 1,160
$
13
$
$
$
$
$
$
$
9
21
30
9
2
87
89
3
23
17
43
$ 666
9
3
17
1
$ 696
$ 565
181
Notes to Financial StatementsSouthern Company 2021 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 certain acquisitions whereby it is primarily obligated to make generation-
based payments to the seller, which commenced at the commercial operation of the respective facility and continue through 2026.
The obligations are categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable
inputs for the forecasted facility generation in MW-hours, as well as other inputs such as a fixed dollar amount per MW-hour, and a
discount rate. The fair value of contingent consideration reflects the net present value of expected payments and any periodic change
arising from forecasted generation is expected to be immaterial.
Southern Power also has payment obligations through 2040 whereby it must reimburse the transmission owners for interconnection
facilities and network upgrades constructed to support connection of a Southern Power generating facility to the transmission system.
The obligations are categorized as Level 2 under Fair Value Measurements as the fair value is determined using observable inputs for the
contracted amounts and reimbursement period, as well as a discount rate. The fair value of the obligations reflects the net present value
of expected payments.
“Other investments” include investments traded in the open market that have maturities greater than 90 days, which are categorized as
Level 2 under Fair Value Measurements and are comprised of corporate bonds, bank certificates of deposit, treasury bonds, and/or agency
bonds.
The fair value measurements of private equity investments held in Alabama Power’s nuclear decommissioning trusts that are calculated
at net asset value per share (or its equivalent) as a practical expedient totaled $150 million and $76 million at December 31, 2021 and
2020, respectively. Unfunded commitments related to the private equity investments totaled $69 million and $73 million at December 31,
2021 and 2020, respectively. Private equity investments include high-quality private equity funds across several market sectors and funds
that invest in real estate assets. Private equity funds do not have redemption rights. Distributions from these funds will be received as the
underlying investments in the funds are liquidated.
182
Notes to Financial StatementsSouthern Company 2021 Annual Report At December 31, 2021 and 2020, other financial instruments for which the carrying amount did not equal fair value were as follows:
At December 31, 2021:
Long-term debt, including securities due within one year:
Carrying amount
Fair value
At December 31, 2020:
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)
$52.1
57.1
$ 9.7
10.9
$13.6
15.1
$48.3
56.3
$ 8.9
10.7
$12.8
15.2
$1.5
1.6
$1.4
1.6
$3.7
4.1
$3.7
4.2
$6.9
7.8
$6.6
8.0
(*) The long-term debt of Southern Company Gas is recorded at amortized cost, including the fair value adjustments at the effective date of the 2016 merger
with Southern Company. Southern Company Gas amortizes the fair value adjustments over the remaining lives of the respective bonds, the latest being
through 2043.
The fair values are determined using Level 2 measurements and are based on quoted market prices for the same or similar issues or on the
current rates available to the Registrants.
Commodity Contracts with Level 3 Valuation Inputs
Prior to July 1, 2021, Southern Company Gas had Level 3 physical natural gas forward contracts related to Sequent. See Note 15 under
“Southern Company Gas” for information regarding the sale of Sequent. The following table provides a reconciliation of Southern Company
Gas’ Level 3 contracts during 2021.
Beginning balance
Instruments realized or otherwise settled during period
Changes in fair value
Sale of Sequent
Ending balance
2021
(in millions)
$ 28
(6)
(4)
(18)
$ —
Changes in fair value of Level 3 instruments represent changes in gains and losses reported on Southern Company Gas’ statements of
income in natural gas revenues prior to the sale of Sequent.
183
Notes to Financial StatementsSouthern Company 2021 Annual Report 14. DERIVATIVES
Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas are exposed to market
risks, including commodity price risk, interest rate risk, weather risk, and occasionally foreign currency exchange rate risk. To manage the
volatility attributable to these exposures, each company nets its exposures, where possible, to take advantage of natural offsets and
enters into various derivative transactions for the remaining exposures pursuant to each company’s policies in areas such as counterparty
exposure and risk management practices. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas’ wholesale gas operations
used various contracts in its commercial activities that generally met the definition of derivatives. For the traditional electric operating
companies, Southern Power, and Southern Company Gas’ other businesses, each company’s policy is that derivatives are to be used
primarily for hedging purposes and mandates strict adherence to all applicable risk management policies. Derivative positions are
monitored using techniques including, but not limited to, market valuation, value at risk, stress testing, and sensitivity analysis. Derivative
instruments are recognized at fair value in the balance sheets as either assets or liabilities and are presented on a net basis. See Note 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 traditional electric operating companies, Southern Power, and Southern Company Gas enter into energy-related derivatives to hedge
exposures to electricity, natural gas, and other fuel price changes. However, due to cost-based rate regulations and other various cost
recovery mechanisms, the traditional electric operating companies and the natural gas distribution utilities have limited exposure to
market volatility in energy-related commodity prices. Each of the traditional electric operating companies and certain of the natural gas
distribution utilities of Southern Company Gas manage fuel-hedging programs, implemented per the guidelines of their respective state
PSCs or other applicable state regulatory agencies, through the use of financial derivative contracts, which are expected to continue to
mitigate price volatility. The traditional electric operating companies (with respect to wholesale generating capacity) and Southern Power
have limited exposure to market volatility in energy-related commodity prices because their long-term sales contracts shift substantially
all fuel cost responsibility to the purchaser. However, the traditional electric operating companies and Southern Power may be exposed to
market volatility in energy-related commodity prices to the extent any uncontracted capacity is used to sell electricity. Southern Company
Gas retains exposure to price changes that can, in a volatile energy market, be material and can adversely affect its results of operations.
Southern Company Gas also enters into weather derivative contracts as economic hedges in the event of warmer-than-normal weather.
Exchange-traded options are carried at fair value, with changes reflected in operating revenues. Non-exchange-traded options are
accounted for using the intrinsic value method. Changes in the intrinsic value for non-exchange-traded contracts are reflected in
operating revenues.
Energy-related derivative contracts are accounted for under one of three methods:
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.
184
Notes to Financial StatementsSouthern Company 2021 Annual Report At December 31, 2021, 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
Longest
Hedge Date
Longest
Non-Hedge Date
(in millions)
311
74
89
75
5
68
2030
2024
2024
2025
2030
2024
2025
—
—
—
2022
2025
(*) Southern Company Gas’ derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas
and a short position is a contract to sell natural gas. Southern Company Gas’ volume represents the net of long natural gas positions of 74 million mmBtu
and short natural gas positions of 6 million mmBtu at December 31, 2021, which is also included in Southern Company’s total volume. See Note 15 under
“Southern Company Gas” for information regarding the sale of Sequent.
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 26 million mmBtu for Southern Company, which includes 6 million mmBtu for Alabama Power,
8 million mmBtu for Georgia Power, 4 million mmBtu for Mississippi Power, and 8 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, 2022 are immaterial for all Registrants.
Interest Rate Derivatives
Southern Company and certain subsidiaries may enter into interest rate derivatives to hedge exposure to changes in interest rates.
Derivatives related to existing variable rate securities or forecasted transactions are accounted for as cash flow hedges where the
derivatives’ fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and presented on the same
income statement line item as the earnings effect of the hedged transactions. Derivatives related to existing fixed rate securities are
accounted for as fair value hedges, where the derivatives’ fair value gains or losses and hedged items’ fair value gains or losses are both
recorded directly to earnings on the same income statement line item. Fair value gains or losses on derivatives that are not designated or
fail to qualify as hedges are recognized in the statements of income as incurred.
At December 31, 2021, the following interest rate derivatives were outstanding:
Notional
Amount
Interest Rate
Received
Weighted Average
Interest Rate Paid
Hedge
Maturity Date
Fair Value Hedges of Existing Debt
Southern Company parent
Southern Company parent
Southern Company Gas
Southern Company
(in millions)
$ 400
1,000
500
$1,900
1.75%
3.70%
1.75%
1-month LIBOR + 0.68%
1-month LIBOR + 2.36%
1-month LIBOR + 0.38%
March 2028
April 2030
January 2031
Fair Value
Gain (Loss)
December 31,
2021
(in millions)
$ (5)
(6)
1
$(10)
For cash flow hedge interest rate derivatives, the estimated pre-tax gains (losses) expected to be reclassified from AOCI to interest expense
for the year ending December 31, 2022 total $(21) million for Southern Company and are immaterial for all other Registrants. Deferred
gains and losses related to interest rate derivatives are expected to be amortized into earnings through 2051 for Southern Company, 2051
for Alabama Power, 2044 for Georgia Power, 2028 for Mississippi Power, and 2046 for Southern Company Gas.
Foreign Currency Derivatives
Southern Company and certain subsidiaries, including Southern Power, may enter into foreign currency derivatives to hedge exposure
to changes in foreign currency exchange rates, such as that arising from the issuance of debt denominated in a currency other than U.S.
dollars. Derivatives related to forecasted transactions are accounted for as cash flow hedges where the derivatives’ fair value gains or
185
Notes to Financial StatementsSouthern Company 2021 Annual Report 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, 2021, the following foreign currency derivatives were outstanding:
Fair Value Hedges of Existing Debt
Southern Company parent
Cash Flow Hedges of Existing Debt
Southern Power
Southern Power
Southern Power total
Southern Company
Pay
Notional
Pay
Rate
Receive
Notional
Receive
Rate
(in millions)
(in millions)
Hedge
Maturity
Date
Fair Value
Gain (Loss)
December 31, 2021
(in millions)
$1,476
3.39%
€ 1,250
1.88%
September 2027
2.95%
3.78%
$ 677
564
$1,241
$2,717
€ 600
500
€ 1,100
€ 2,350
1.00%
1.85%
June 2022
June 2026
$(63)
$ (5)
(10)
$(15)
$(78)
The estimated pre-tax gains (losses) related to Southern Power’s foreign currency derivatives accounted for as cash flow hedges expected
to be reclassified from AOCI to earnings for the year ending December 31, 2022 are $(13) million.
Derivative Financial Statement Presentation and Amounts
Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas enter into derivative
contracts that may contain certain provisions that permit intra-contract netting of derivative receivables and payables for routine billing
and offsets related to events of default and settlements. Southern Company and certain subsidiaries also utilize master netting agreements
to mitigate exposure to counterparty credit risk. These agreements may contain provisions that permit netting across product lines and
against cash collateral. The fair value amounts of derivative assets and liabilities on the balance sheets are presented net to the extent that
there are netting arrangements or similar agreements with the counterparties.
186
Notes to Financial StatementsSouthern Company 2021 Annual Report At December 31, 2021 and 2020, 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
Southern Company
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities
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 value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities
Other deferred charges and assets/Other deferred credits and liabilities
Interest rate derivatives:
Assets from risk management activities/Other current liabilities
Other deferred charges and assets/Other deferred credits and liabilities
Foreign currency derivatives:
Assets from risk management activities/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
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/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)
Alabama Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
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
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
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
2021
2020
Assets
Liabilities
Assets
Liabilities
(in millions)
$129
72
$201
$
7
1
19
—
—
—
$ 27
$
9
1
$ 10
$238
$ (25)
$213
$ 30
6
$ 36
$
5
—
—
29
39
40
$113
$
4
—
$
4
$153
$ (28)
$125
$ 24
18
$ 42
$
3
—
20
—
—
87
$ 110
$ 388
270
$ 658
$ 810
$(529)
$ 281
$ 11
19
$ 30
$
5
—
—
—
23
—
$ 28
$ 331
232
$ 563
$ 621
$ (557)
$ 64
$ 30
25
$ 55
$ (5)
$ 50
$
9
2
$ 11
$ (5)
6
$
$
7
5
$ 12
(7)
$
5
$
$
2
5
7
$
$
(7)
$ —
$ 54
21
$ 75
$ (8)
$ 67
$
6
2
$
8
$ (8)
$ —
$
7
8
$ 15
$ (12)
3
$
$
5
8
$ 13
$ (12)
1
$
187
Notes to Financial StatementsSouthern Company 2021 Annual Report Derivative Category and Balance Sheet Location
Mississippi Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
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:
Other current assets/Other current liabilities
Other deferred charges and assets/Other deferred credits and liabilities
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
Derivatives not designated as hedging instruments
Energy-related derivatives:
Other current assets/Other current liabilities
Net amounts recognized in the Balance Sheets
Southern Company Gas
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
2021
2020
Assets
Liabilities
Assets
Liabilities
(in millions)
$30
26
$56
$ (4)
$52
$ 2
1
—
—
$ 3
$ 1
$ 4
$ 3
2
$ 5
$ (4)
$ 1
$ —
—
16
—
$ 16
$
$
$
$
$
4
5
9
(7)
2
2
—
$
$
$
$
$
3
6
9
(7)
2
2
—
—
87
$ 89
23
—
$ 25
$ —
$ 16
$ —
$ 89
$
1
$ 26
Assets from risk management activities/Other current liabilities
$15
$ 12
$
6
$
1
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities
$ 5
$ 5
$
1
$
3
Interest rate derivatives:
Assets from risk management activities/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
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/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)
6
—
$11
$ 8
1
$ 9
$35
$ (8)
$27
—
6
$ 11
$ 4
—
$ 4
$ 27
$(11)
$ 16
—
—
1
$
—
—
3
$
$ 388
270
$ 658
$ 665
$(503)
$ 162
$ 330
232
$ 562
$ 566
$ (531)
$ 35
(a) Gross amounts offset include cash collateral held on deposit in broker margin accounts of $3 million and $28 million at December 31, 2021 and 2020, respectively.
(b) Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives for all periods presented.
188
Notes to Financial StatementsSouthern Company 2021 Annual Report At December 31, 2021 and 2020, 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
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
At December 31, 2021:
Energy-related derivatives:
Other regulatory assets, current
Other regulatory liabilities, current
Other regulatory liabilities, deferred
Total energy-related derivative gains (losses)
At December 31, 2020:
Energy-related derivatives:
Other regulatory assets, deferred
Other regulatory liabilities, current
Other regulatory liabilities, deferred
Total energy-related derivative gains (losses)
(in millions)
$ —
48
19
$67
$ (1)
2
1
$ 2
$ (6)
28
22
$44
$ —
5
1
$ 6
$ —
27
24
$51
$ (1)
1
—
$ —
$ (17)
107
65
$155
$ (2)
12
2
$ 12
Southern
Company
Gas
$(11)
4
—
$ (7)
$ —
4
—
$ 4
For the years ended December 31, 2021, 2020, and 2019, 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
Interest rate derivatives
Total
2021
2020
2019
(in millions)
$
34
5
(103 )
(3 )
$ (67 )
$ (8)
(26)
48
—
$ 14
$ (13)
(57)
(84)
—
$(154)
$ —
$ (3)
$ (59)
$
12
(103 )
$ (91 )
$
$
22
—
22
$ (2)
48
$ 46
$ (6)
(23 )
$(29)
$
(4)
(84)
$ (88)
$
$
(9)
2
(7)
(*) Represents amounts excluded from the assessment of effectiveness for which the difference between changes in fair value and periodic amortization is
recorded in OCI.
The pre-tax effects of interest rate derivatives designated as cash flow hedging instruments on AOCI were immaterial for the other
Registrants for all years presented.
189
Notes to Financial StatementsSouthern Company 2021 Annual Report The pre-tax effects of cash flow and fair value hedge accounting on income for the years ended December 31, 2021, 2020, and 2019 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 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)
2021
2020
(in millions)
$
972
(8)
3,518
(3)
(1,821)
(26)
(23)
27
336
114
—
—
$
494
(3)
(151)
(23)
19
114
$ 1,619
17
3,565
9
(1,837)
(27)
(24)
(30)
456
(104)
(63)
3
$
517
9
(147)
(24)
10
(104)
$ 1,619
17
2019
$ 1,319
(2)
3,038
(6)
(1,736)
(20)
(24)
42
252
(24)
—
—
$
479
(6)
(169)
(24)
47
(24)
$
972
(8)
$ 1,319
(2)
(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 and fair value hedge accounting on income for interest rate derivatives and energy-related derivatives
were immaterial for the other Registrants for all years presented.
At December 31, 2021 and 2020, the following amounts were recorded on the balance sheets related to cumulative basis adjustments for
fair value hedges:
Carrying Amount of the Hedged Item
Cumulative Amount of Fair Value
Hedging Adjustment included in
Carrying Amount of the Hedged Item
At December 31,
2021
At December 31,
2020
At December 31,
2021
At December 31,
2020
(in millions)
(in millions)
$ —
(3,280)
$(1,509)
—
$ (493)
$ —
$ —
9
$ 2
$(10)
—
$ —
Balance Sheet Location of Hedged Items
Southern Company
Securities due within one year
Long-term debt
Southern Company Gas
Long-term debt
190
Notes to Financial StatementsSouthern Company 2021 Annual Report 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, 2021, 2020, and 2019 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
2021
$(117)
(27)
$(144)
Gain (Loss)
2020
(in millions)
$ 134
15
$ 149
2019
$223
10
$233
(*) Excludes the impact of weather derivatives recorded in natural gas revenues of $9 million and $3 million for 2020 and 2019, 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
Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas do not have any credit
arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There
are certain derivatives that could require collateral, but not accelerated payment, in the event of various credit rating changes of certain
Southern Company subsidiaries. At December 31, 2021, the Registrants had no collateral posted with derivative counterparties to satisfy
these arrangements.
For the applicable Registrants, the fair value of interest rate and energy-related derivative liabilities with contingent features and the
maximum potential collateral requirements arising from the credit-risk-related contingent features, at a rating below BBB- and/or Baa3,
were immaterial at December 31, 2021. The maximum potential collateral requirements arising from the credit-risk-related contingent
features for the traditional electric operating companies and Southern Power include certain agreements that could require collateral in the
event that one or more Southern Company power pool participants has a credit rating change to below investment grade. Following the
sale of Gulf Power to NextEra Energy, Gulf Power has continued participating in the Southern Company power pool; however, on
December 21, 2021, NextEra Energy provided a 180-day notice of its intention to cease such participation.
Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. If collateral is required, fair value amounts
recognized for the right to reclaim cash collateral or the obligation to return cash collateral are not offset against fair value amounts
recognized for derivatives executed with the same counterparty.
Alabama Power and Southern Power maintain accounts with certain regional transmission organizations to facilitate financial derivative
transactions and they may be required to post collateral based on the value of the positions in these accounts and the associated margin
requirements. At December 31, 2021, cash collateral posted in these accounts was immaterial. Southern Company Gas maintains accounts
with brokers or the clearing houses of certain exchanges to facilitate financial derivative transactions. Based on the value of the positions
in these accounts and the associated margin requirements, Southern Company Gas may be required to deposit cash into these accounts. At
December 31, 2021, cash collateral held on deposit in broker margin accounts was immaterial.
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.
191
Notes to Financial StatementsSouthern Company 2021 Annual Report 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 January 2019, Southern Company completed the sale of all of the capital stock of Gulf Power to a wholly-owned subsidiary of NextEra
Energy, for an aggregate cash purchase price of approximately $5.8 billion (less $1.3 billion of indebtedness assumed), including the final
working capital adjustments. The gain associated with the sale of Gulf Power totaled $2.6 billion pre-tax ($1.4 billion after tax).
In July 2019, PowerSecure completed the sale of its utility infrastructure services business for approximately $65 million, including the final
working capital adjustments. In contemplation of this sale, a goodwill impairment charge of $32 million was recorded in the second quarter
2019. In December 2019, PowerSecure completed the sale of its lighting business for approximately $9 million, which included cash of
$4 million and a note receivable from the buyer of $5 million. In contemplation of this sale, an impairment charge of $18 million was
recorded in the third quarter 2019 related to goodwill, identifiable intangibles, and other assets.
In December 2019, Southern Company completed the sale of one of its leveraged lease investments for an aggregate cash purchase price
of approximately $20 million. The sale resulted in an immaterial gain.
In connection with the annual impairment analysis of a leveraged lease investment during the fourth quarter 2020, Southern Company
management concluded that the estimated residual value of the generation assets should be reduced due to significant uncertainty as to
whether the related natural gas generation assets would continue to operate at the end of the lease term in 2040 and recorded a $34 million
($17 million after tax) impairment charge. Also during the fourth quarter 2020, Southern Company management initiated steps to sell the
investment and reclassified it as held for sale at December 31, 2020. In the fourth quarter 2020 and the second quarter 2021, additional
charges of $18 million ($14 million after tax) and $7 million ($6 million after tax), respectively, were recorded to further reduce the investment
to its estimated fair value, less costs to sell. On October 29, 2021, Southern Company completed the sale 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.
On December 13, 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 August 2020, Alabama Power completed its acquisition of the Central Alabama Generating Station, an approximately 885-MW combined
cycle generation facility in Autauga County, Alabama. The total purchase price was $461 million, of which $452 million was related to
net assets recorded within property, plant, and equipment on the balance sheet and the remainder primarily related to inventory, current
receivables, and accounts payable. Alabama Power assumed an existing power sales agreement under which the full output of the
generating facility remains committed to another third party for its remaining term of approximately three years. During the remaining
term, the estimated revenues from the power sales agreement are expected to offset the associated costs of operation. See Notes 2 and 9
under “Alabama Power” and “Lessor,” respectively, for additional information.
On September 23, 2021, Alabama Power entered into an agreement to acquire all of the equity interests in Calhoun Power Company, LLC,
which owns and operates the Calhoun Generating Station. See Note 2 under “Alabama Power – Certificates of Convenience and Necessity”
for additional information.
Southern Power
Southern Power’s acquisition-related costs for the projects discussed under “Asset Acquisitions” and “Construction Projects” below were
expensed as incurred and were not material for any of the years presented.
192
Notes to Financial StatementsSouthern Company 2021 Annual Report Asset Acquisitions
Project Facility
Resource
Seller
Asset Acquisitions During 2021
Deuel Harvest(a)
Asset Acquisitions During 2020
Beech Ridge II
Asset Acquisitions During 2019
DSGP(c)
Wind
Wind
Invenergy
Renewables LLC
Invenergy
Renewables LLC
Fuel Cell
Bloom Energy
Approximate
Nameplate
Capacity (MW)
Location
Southern
Power
Ownership
Percentage
COD
PPA Contract
Period
300
Deuel County,
SD
100% of
Class B
February
2021
25 years
and 15 years
56
28
Greenbrier
County, WV
100% of
Class A(b)
May
2020
12 years
Delaware
100% of
Class B
N/A(d)
15 years(e)
(a) On March 26, 2021, Southern Power acquired a controlling interest in the project from Invenergy Renewables LLC and, on March 30, 2021, Southern Power
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.
(b) In May 2020, Southern Power purchased a controlling interest and now consolidates the project’s operating results in its financial statements. The Class B
member owns the noncontrolling interest.
(c) During 2019, Southern Power purchased a controlling interest and now consolidates the project’s operating results in its financial statements. The Class A
and Class C members each own a noncontrolling interest. Southern Power records net income attributable to noncontrolling interests for approximately
10 MWs of the facility.
(d) Southern Power’s 18-MW share of the facility was repowered between June and August 2019. In December 2019, a Class C member joined the existing
partnership between the Class A member and Southern Power and made an investment to repower the remaining 10 MWs.
(e) Remaining PPA contract period at the time of acquisition.
Construction Projects
During 2021, Southern Power completed construction of and placed in service the Glass Sands wind facility, 73 MWs of the Garland battery
energy storage facility, and 32 MWs of the Tranquillity battery energy storage facility. At December 31, 2021, total costs of construction
incurred for these projects were $383 million. Southern Power continues construction of the remainder of the Garland and Tranquillity
battery energy storage facilities and expects total aggregate construction costs to be between $230 million and $270 million. The ultimate
outcome of these matters cannot be determined at this time. See Note 9 under “Lessor” for additional information.
Project Facility
Projects Under Construction
at December 31, 2021
Approximate
Nameplate
Capacity (MW)
Resource
Location
Actual/Expected COD
Tranquillity Solar Storage(a)
Battery energy storage system
Garland Solar Storage(a)
Battery energy storage system
72
88
Fresno County, CA
Kern County, CA
November 2021 and
first quarter 2022(b)
September 2021,
December 2021, and
first quarter 2022(c)
PPA
Contract
Period
20 years
20 years
Projects Completed During 2021
Glass Sands(d)
Projects Completed During 2020
Skookumchuck(e)
Reading(f)
Wind
Wind
Wind
118
Murray County, OK
November 2021
12 years
136
200
Lewis and Thurston
Counties, WA
Osage and Lyon
Counties, KS
November 2020
20 years
May 2020
12 years
(a) In December 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 the third quarter 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.
193
Notes to Financial StatementsSouthern Company 2021 Annual Report (b) The facility has a total capacity of 72 MWs, of which 32 MWs were placed in service in November 2021 and the remaining MWs are expected to be placed
in service later in the first quarter 2022.
(c) The facility has a total capacity of 88 MWs, of which 73 MWs were placed in service during 2021 and the remaining MWs are expected to be placed in
service later in the first quarter 2022.
(d) In December 2020, Southern Power purchased 100% of the membership interests of the Glass Sands facility.
(e) In 2019, Southern Power purchased 100% of the membership interests of the Skookumchuck facility pursuant to a joint development arrangement.
In November 2020, Southern Power completed a tax equity transaction whereby it received $121 million, resulting in 100% ownership of the Class B
membership interests. Southern Power subsequently sold a noncontrolling interest in the Class B membership interests and now retains the controlling
ownership interest in the facility.
(f) In 2018, Southern Power purchased 100% of the membership interests of the Reading facility pursuant to a joint development arrangement. In June 2020,
Southern Power completed a tax equity transaction whereby it received $156 million and owns 100% of the Class B membership interests.
Development Projects
Southern Power continues to evaluate and refine the deployment of the remaining wind turbine equipment purchased in 2016 and 2017
for development and construction projects. Wind projects utilizing equipment purchased in 2016 and 2017, and reaching commercial
operation by the end of 2021 and 2022, are expected to qualify for 100% and 80% PTCs, respectively. The significant majority of this
equipment either has been deployed to projects that have been completed, are under construction, or are probable of completion, or has
been sold to third parties. Gains on wind turbine equipment contributed to various equity method investments totaled approximately
$37 million in 2021. Gains on wind turbine equipment sales were immaterial in 2020 and totaled approximately $17 million in 2019.
Sales of Natural Gas and Biomass Plants
In June 2019, Southern Power completed the sale of its equity interests in Plant Nacogdoches, a 115-MW biomass facility located
in Nacogdoches County, Texas, to Austin Energy, for a purchase price of approximately $461 million, including final working capital
adjustments. Southern Power recorded a gain of $23 million ($88 million after tax) on the sale.
In January 2020, Southern Power completed the sale of its equity interests in Plant Mankato (including the 385-MW expansion unit
completed in May 2019) to a subsidiary of Xcel Energy Inc. for a purchase price of approximately $663 million, including final working
capital adjustments. The sale resulted in a gain of approximately $39 million ($23 million after tax).
Plant Nacogdoches and Plant Mankato represented individually significant components of Southern Power. Pre-tax income for these
components for the years ended December 31, 2020 and 2019 are presented below:
Earnings before income taxes:
Plant Nacogdoches(a)(b)
Plant Mankato(a)(c)
2020
2019
(in millions)
N/A
$2
$13
$29
(a) Earnings before income taxes reflect the cessation of depreciation and amortization on the long-lived assets being sold upon classification as held for sale
(November 2018 for Plant Mankato and April 2019 for Plant Nacogdoches).
(b) 2019 amount represents the period from January 1, 2019 to June 13, 2019 (the divestiture date).
(c) 2020 amount represents the period from January 1, 2020 to January 17, 2020 (the divestiture date).
Southern Company Gas
Sale of Sequent
On July 1, 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). As a result of the sale, changes in state apportionment rates resulted in $85 million of additional
tax expense.
Prior to the sale, Southern Company Gas had existing agreements in place in which it guaranteed the payment performance of Sequent.
Southern Company Gas will continue to guarantee Sequent’s payment performance for a period of time as Williams Field Services Group
obtains releases from these obligations. At December 31, 2021, the remaining obligations subject to the payment performance guarantee
were immaterial. Changes in the price of natural gas, market conditions, and the number of open contracts may change the amount that
Southern Company Gas is required to guarantee for Sequent each month.
194
Notes to Financial StatementsSouthern Company 2021 Annual Report Sale of Pivotal LNG and Atlantic Coast Pipeline
In March 2020, Southern Company Gas completed the sale of its interests in Pivotal LNG and Atlantic Coast Pipeline to Dominion Modular
LNG Holdings, Inc. and Dominion Atlantic Coast Pipeline, LLC, respectively, with aggregate proceeds of $178 million, including final working
capital adjustments. The loss associated with the transactions was immaterial. During 2019, based on the terms of these transactions,
Southern Company Gas recorded an asset impairment charge, exclusive of the contingent payments, for Pivotal LNG of approximately
$24 million ($17 million after tax) as of December 31, 2019. In connection with the sale, Southern Company Gas was entitled to two
$5 million payments contingent upon Dominion Modular LNG Holdings, Inc. meeting certain milestones related to Pivotal LNG. Southern
Company Gas received the first payment on April 22, 2021 and expects to receive the second payment in March 2022.
Sale of Natural Gas Storage Facility
In December 2020, Southern Company Gas completed the sale of Jefferson Island to EnLink Midstream, LLC for a total purchase price of
$33 million, including estimated working capital adjustments. The gain associated with the sale totaled $22 million pre-tax ($16 million
after tax). In 2019, Southern Company Gas recorded a pre-tax impairment charge of $91 million ($69 million after-tax) related to
Jefferson Island.
Sale of Triton
In May 2019, Southern Company Gas sold its investment in Triton, a cargo container leasing company that was aggregated into Southern
Company Gas’ all other segment. This disposition resulted in a pre-tax loss of $6 million and a net after-tax gain of $7 million as a result of
reversing a $13 million federal income tax valuation allowance.
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
$515 million, $364 million, and $398 million in 2021, 2020, and 2019, respectively. Revenues from sales of natural gas from Southern
Company Gas to the traditional electric operating companies and Southern Power were immaterial and $18 million, respectively, in 2021
(which represented sales from Sequent through June 30, 2021), immaterial and $26 million, respectively, in 2020, and $14 million and
$64 million, respectively, in 2019. The “All Other” column includes the Southern Company parent entity, which does not allocate operating
expenses to business segments. Also, this category includes segments below the quantitative threshold for separate disclosure. These
segments include providing distributed energy and resilience solutions and deploying microgrids for commercial, industrial, governmental,
and utility customers, as well as investments in telecommunications and leveraged lease projects. All other inter-segment revenues are
not material.
195
Notes to Financial StatementsSouthern Company 2021 Annual Report Financial data for business segments and products and services for the years ended December 31, 2021, 2020, and 2019 was as follows:
Electric Utilities
Traditional
Electric
Operating
Companies
Southern
Power
Eliminations
Total
Southern
Company
Gas
All
Other
Eliminations
Consolidated
(in millions)
$16,614
$ 2,216
$ (530)
$ 18,300
$ 4,380
$ 582
$ (149)
$ 23,113
2,436
20
1
821
232
1,981
—
39
89,051
517
1
—
147
(13)
266
2
—
13,390
—
—
—
—
—
2,953
21
1
968
219
—
—
—
(667)
2,247
2
39
101,774
536
—
50
238
275
539
5,015
—
23,560
76
4
24
631
(227)
(384)
263
3
2,975
—
(3)
1
—
—
(9)
—
—
(775)
3,565
22
76
1,837
267
2,393
5,280
42
127,534
$ 15,135
$ 1,733
$ (371)
$ 16,497
$ 3,434
$ 596
$ (152)
$ 20,375
2,447
26
—
825
514
2,877
—
5
85,486
494
4
—
151
3
238
2
—
13,235
—
—
—
—
—
—
—
—
(680)
2,941
30
—
976
517
3,115
2
5
98,041
500
5
141
231
173
590
5,015
—
22,630
77
6
12
614
(297)
(592)
263
55
3,168
—
(4)
—
—
—
6
—
—
(904)
3,518
37
153
1,821
393
3,119
5,280
60
122,935
$ 15,569
$ 1,938
$ (412)
$ 17,095
$ 3,792
$ 690
$ (158)
$ 21,419
1,993
38
2
818
764
2,929
—
—
81,063
479
9
3
169
(56)
339
2
618
14,300
—
—
—
—
—
—
—
—
(713)
2,472
47
5
987
708
3,268
2
618
94,650
487
3
157
232
130
585
5,015
171
21,687
79
16
—
517
960
908
263
—
3,511
—
(6)
—
—
—
(22)
—
—
(1,148)
3,038
60
162
1,736
1,798
4,739
5,280
789
118,700
2021
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)(e)(f)
Goodwill
Assets held for sale
Total assets
2020
Operating revenues
Depreciation and
amortization
Interest income
Earnings from equity
method investments
Interest expense
Income taxes (benefit)
Segment net income
(loss)(a)(b)(f)(g)(h)
Goodwill
Assets held for sale
Total assets
2019
Operating revenues
Depreciation and
amortization
Interest income
Earnings from equity
method investments
Interest expense
Income taxes (benefit)
Segment net income
(loss)(a)(f)(i)(j)(k)
Goodwill
Assets held for sale
Total assets
(a) Attributable to Southern Company.
(b) For the traditional electric operating companies, includes pre-tax charges at Georgia Power for estimated losses associated with the construction of Plant
Vogtle Units 3 and 4 of $1.7 billion ($1.3 billion after tax) in 2021 and $325 million ($242 million after tax) in 2020. See Note 2 under “Georgia Power –
Nuclear Construction” for additional information.
(c) 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.
196
Notes to Financial StatementsSouthern Company 2021 Annual Report (d) 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.
(e) 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.
(f) For the “All Other” column, includes pre-tax impairment charges totaling $7 million ($6 million after tax) in 2021, $206 million ($105 million after tax) in
2020, and $17 million ($13 million after tax) in 2019 related to leveraged lease investments. See Notes 9 and 15 under “Southern Company Leveraged
Lease” and “Southern Company,” respectively, for additional information.
(g) For Southern Power, includes a $39 million pre-tax gain ($23 million gain after tax) on the sale of Plant Mankato. See Note 15 under “Southern Power” for
additional information.
(h) For Southern Company Gas, includes a $22 million pre-tax gain ($16 million gain after tax) on the sale of Jefferson Island. See Note 15 under “Southern
Company Gas” for additional information.
(i) For Southern Power, includes a $23 million pre-tax gain ($88 million gain after tax) on the sale of Plant Nacogdoches. See Note 15 under “Southern Power”
for additional information.
(j) For Southern Company Gas, includes pre-tax impairment charges totaling $115 million ($86 million after tax). See Note 15 under “Southern Company Gas”
for additional information.
(k) For the “All Other” column, includes the pre-tax gain associated with the sale of Gulf Power of $2.6 billion ($1.4 billion after tax) and the pre-tax loss,
including related impairment charges, on the sales of certain PowerSecure business units totaling $58 million ($52 million after tax). See Note 15 under
“Southern Company” for additional information.
Products and Services
Year
2021
2020
2019
Year
2021
2020
2019
Electric Utilities’ Revenues
Retail
Wholesale
Other
Total
(in millions)
$14,852
13,643
14,084
$2,455
1,945
2,152
$993
909
859
$18,300
16,497
17,095
Southern Company Gas’ Revenues
Gas
Distribution
Operations
Gas
Marketing
Services
All Other
Total
$3,656
2,902
3,001
(in millions)
$475
408
456
$249
124
335
$4,380
3,434
3,792
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. Gas pipeline investments also includes a 20% ownership interest in the PennEast Pipeline project,
which was cancelled in September 2021, and through its March 24, 2020 sale, included a 5% ownership interest in the Atlantic Coast
Pipeline construction project. 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 Jefferson Island through its sale on December 1, 2020, Pivotal LNG through its sale on
March 24, 2020, and the investment in Triton through its sale on May 29, 2019.
197
Notes to Financial StatementsSouthern Company 2021 Annual Report Financial data for business segments for the years ended December 31, 2021, 2020, and 2019 was as follows:
Gas
Distribution
Operations
Gas
Pipeline
Investments
Wholesale
Gas
Services(a)
Gas
Marketing
Services
(in millions)
Total
All Other
Eliminations
Consolidated
2021
Operating revenues
Depreciation and amortization
Operating income (loss)
Earnings from equity method
investments
Interest expense
Income taxes (benefit)
Segment net income (loss)(b)(c)(d)
Total assets
2020
Operating revenues
Depreciation and amortization
Operating income (loss)
Earnings from equity method
investments
Interest expense
Income taxes (benefit)
Segment net income (loss)(e)
Total assets
2019
Operating revenues
Depreciation and amortization
Operating income (loss)
Earnings from equity method
investments
Interest expense
Income taxes (benefit)
Segment net income (loss)(f)
Total assets
$ 3,679
482
708
—
207
120
412
20,917
$ 2,952
442
655
—
192
114
390
19,090
$ 3,028
422
573
—
187
63
337
18,204
$
32
5
21
50
25
27
19
1,467
$
32
5
20
141
29
33
99
1,597
$
32
5
20
162
30
58
94
1,678
$ 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
$ 74
1
20
$ 408
22
119
$ 3,466
470
814
$
36
30
(7)
—
4
3
14
850
—
3
28
89
1,503
141
228
178
592
23,040
—
3
(5)
(2)
11,336
$ 294
1
219
$ 456
26
112
$ 3,810
454
924
$
44
33
(154)
$
$
$
(32)
—
—
$ 4,380
536
1,055
—
—
—
—
(12,525)
50
238
275
539
23,560
(68)
—
5
$ 3,434
500
812
—
—
—
—
(11,746)
141
231
173
590
22,630
(62)
—
—
$ 3,792
487
770
—
5
52
163
850
—
3
27
83
1,496
162
225
200
677
22,228
(5)
7
(70)
(92)
10,759
—
—
—
—
(11,300)
157
232
130
585
21,687
(a) The revenues for wholesale gas services are netted with costs associated with its energy and risk management activities. A reconciliation of operating
revenues and intercompany revenues is shown in the following table.
2021
2020
2019
Third Party
Gross
Revenues
Inter -
company
Revenues
Total
Gross
Revenues
Less Gross
Gas Costs
Operating
Revenues
$3,881
4,544
5,703
$ 90
115
275
(in millions)
$3,971
4,659
5,978
$3,783
4,585
5,684
$188
74
294
(b) 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.
(c) For wholesale gas services, includes a pre-tax gain of $121 million ($92 million after tax) related to the sale of Sequent.
(d) For the “All Other” column, includes $85 million of additional tax expense due to changes in state apportionment rates as a result of the sale of Sequent.
(e) For the “All Other” column includes a $22 million pre-tax gain ($16 million gain after tax) on the sale of Jefferson Island.
(f) For the “All Other” column, includes pre-tax impairment charges totaling $115 million ($86 million after tax). See Note 15 under “Southern Company Gas”
for additional information.
198
Notes to Financial StatementsSouthern Company 2021 Annual Report Shareholder Information
Transfer Agent
Electronic Delivery of Proxy Materials
EQ Shareowner Services is Southern Company’s transfer agent,
dividend-paying agent, investment plan administrator and
Any stockholder may enroll for electronic delivery of proxy
materials by logging on at www.icsdelivery.com/so.
registrar. If you have questions concerning your registered
Southern Company shareowner account, please contact:
Environmental, Social and Governance (ESG) Information
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
Southern Company publishes ESG information at
www.southerncompany.com/sustainability.
Common Stock
Southern Company common stock is listed on the NYSE
under the ticker symbol SO. On January 31, 2022,
Southern Company had 103,154 shareholders of record.
The 2021 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.
The Southern Investment Plan is a convenient way to become
Southern Company is a holding company that conducts
a Southern Company shareholder. Participants in the Plan
business through its subsidiaries. Unless the context other-
can purchase additional shares in Southern Company through
wise requires, references to Southern Company’s customers,
optional cash purchases and reinvestment of dividends. The
communities and operations in this 2021 annual report refer to
the customers, communities and operations of its subsidiaries.
Pages 16-198 of this 2021 annual report contain excerpts from
Southern Company’s Annual Report on Form 10-K for the year
ended December 31, 2021, which was filed with the SEC on
February 16, 2022. Information in these pages is provided as
of the February 16, 2022 filing date and has not been updated
for any subsequent events or developments.
Visit our website at www.southerncompany.com
Follow us on Twitter at www.twitter.com/southerncompany
Writing and project management: Terrell McCollum; Additional writing:
Schuyler Baehman, Michael Buteau, Laura Osnard; Design: Leap Communications;
Photography: James Schnepf, Philip Wages; Printing: Sandy Alexander
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.
SouthernCompany.com