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32: R3 Condensed Consolidated Statements of Income HTML 51K
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Equity (Unaudited) - Southern
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APC
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APC (Parenthetical)
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GPC
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GPC (Parenthetical)
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Equity (Unaudited) - GPC
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Equity (Unaudited) - GPC (Parenthetical)
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Income (Unaudited) - MPC
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MPC
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MPC (Parenthetical)
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Equity (Unaudited) - MPC
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77: R48 Condensed Consolidated Statements of Stockholders' HTML 75K
Equity (Unaudited) - GAS
78: R49 Introduction HTML 122K
79: R50 Regulatory Matters HTML 111K
80: R51 Contingencies HTML 56K
81: R52 Revenue from Contracts with Customers and Lease HTML 275K
Income
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Investments
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84: R55 Income Taxes HTML 48K
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86: R57 Fair Value Measurements HTML 261K
87: R58 Derivatives HTML 374K
88: R59 Acquisitions and Dispositions HTML 52K
89: R60 Segment and Related Information HTML 150K
90: R61 Introduction (Policies) HTML 71K
91: R62 Introduction (Tables) HTML 193K
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Income (Tables)
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Investments (Tables)
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100: R71 Segment and Related Information (Tables) HTML 143K
101: R72 Introduction - Schedule of Goodwill (Details) HTML 49K
102: R73 Introduction - Schedule of Other Intangible Assets HTML 86K
(Details)
103: R74 Introduction - Schedule of Amortization of Other HTML 49K
Intangible Assets (Details)
104: R75 Introduction - Schedule of Cash, Cash Equivalents, HTML 75K
and Restricted Cash (Details)
105: R76 Introduction - Depreciation and Amortization HTML 46K
(Details)
106: R77 Regulatory Matters - Schedule of Cost Recovery HTML 69K
Clauses (Details)
107: R78 Regulatory Matters - GPC Integrated Resource Plan HTML 45K
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109: R80 Regulatory Matters - GPC Nuclear Construction Cost HTML 65K
and Schedule (Details)
110: R81 Regulatory Matters - GPC Amendments to the Vogtle HTML 88K
Joint Ownership Agreements (Details)
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Regulatory Matters (Details)
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113: R84 Regulatory Matters - GAS Schedule of HTML 51K
Infrastructure Replacement Programs and Capital
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114: R85 Contingencies - General Litigation Matters HTML 65K
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115: R86 Contingencies - Environmental Remediation HTML 46K
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116: R87 Revenue from Contracts with Customers and Lease HTML 244K
Income - Schedule of Disaggregation of Revenue
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Income - Schedule of Contract Balances (Details)
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Income - Narrative (Details)
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Income - Schedule of Remaining Performance
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Income - Schedule of Lease Income (Details)
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Investments - Narrative (Details)
122: R93 Consolidated Entities and Equity Method HTML 55K
Investments - Schedule of Equity Method
Investments (Details)
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Investments - Schedule of Earnings (Loss) from
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124: R95 Financing - Schedule of Credit Arrangements HTML 91K
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125: R96 Financing - Narrative (Details) HTML 57K
126: R97 Financing - Schedule of Shares Used to Compute HTML 48K
Diluted Earnings Per Share (Details)
127: R98 Income Taxes - Narrative (Details) HTML 46K
128: R99 Retirement Benefits (Details) HTML 113K
129: R100 Fair Value Measurements - Schedule of Assets and HTML 341K
Liabilities Measured at Fair Value (Details)
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(Decrease) In Fair Value Of Funds (Details)
131: R102 Fair Value Measurements - Narrative (Details) HTML 47K
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Instruments for which Carrying Amount did not
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133: R104 Derivatives - Schedule of Energy-Related HTML 60K
Derivatives (Details)
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Derivatives (Details)
136: R107 Derivatives - Schedule of Foreign Currency HTML 65K
Derivatives (Details)
137: R108 Derivatives - Schedule of Derivative Category and HTML 186K
Balance Sheet Location (Details)
138: R109 Derivatives - Schedule of Pre-tax Effects of HTML 72K
Unrealized Derivative Gains (Losses) (Details)
139: R110 Derivatives - Schedule of Pre-Tax Effects of HTML 62K
Hedging on AOCI (Details)
140: R111 Derivatives - Schedule of Pre-Tax Effects of Cash HTML 88K
Flow and Fair Value Hedging on Income (Details)
141: R112 Derivatives - Schedule of Cumulative Basis HTML 49K
Adjustments for Fair Value Hedges (Details)
142: R113 Derivatives - Schedule of Pre-tax Effect of HTML 50K
Interest Rate and Energy Related Derivatives on
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143: R114 Acquisitions and Dispositions - Southern Power HTML 47K
Narrative (Details)
144: R115 Acquisitions and Dispositions - Schedule of HTML 52K
Construction Projects (Details)
145: R116 Segment and Related Information - Narrative HTML 69K
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146: R117 Segment and Related Information - Schedule of HTML 144K
Financial Data for Business Segments (Details)
147: R118 Segment and Related Information - Schedule of HTML 90K
Financial Data for Products and Services (Details)
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iSeries 2017A 5.00% Junior Subordinated Notes due 2077
iGPJA
iNYSE
Southern
Power Company
iSeries 2016A 1.000% Senior Notes due 2022
iSO/22B
iNYSE
Southern
Power Company
iSeries 2016B 1.850% Senior Notes due 2026
iSO/26A
iNYSE
Indicate
by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. iiiiiiYes/////þ
No ¨
Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrants were required to submit such files). iiiiiiYes/////þ
No ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer,""accelerated filer,""smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.
Registrant
iLarge
Accelerated Filer
Accelerated Filer
iiiiiNon-accelerated
Filer////
Smaller Reporting Company
Emerging Growth Company
The Southern Company
X
Alabama
Power Company
X
Georgia Power Company
X
Mississippi Power Company
X
Southern Power Company
X
Southern
Company Gas
X
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. iiiiiiiiiiii☐///////////
Indicate
by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes iiiiii☐/////
No þ (Response applicable to all registrants.)
This
combined Form 10-Q is separately filed by The Southern Company, Alabama Power Company, Georgia Power Company, Mississippi Power Company, Southern Power Company, and Southern Company Gas. Information contained herein relating to any individual registrant is filed by such registrant on its own behalf. Each registrant makes no representation as to information relating to the other registrants.
Alternate Rate Plan approved by the Georgia PSC in 2019 for Georgia Power for the years 2020 through 2022
AFUDC
Allowance for funds used during construction
Alabama
Power
Alabama Power Company
Amended and Restated Loan Guarantee Agreement
Loan guarantee agreement entered into by Georgia Power with the DOE in 2014, as amended and restated in March 2019, under which the proceeds of borrowings may be used to reimburse Georgia Power for Eligible Project Costs incurred in connection with its construction of Plant Vogtle Units 3 and 4
ARO
Asset retirement obligation
Atlanta Gas Light
Atlanta Gas Light Company, a wholly-owned subsidiary of Southern Company Gas
Bechtel
Bechtel
Power Corporation, the primary contractor for the remaining construction activities for Plant Vogtle Units 3 and 4
Bechtel Agreement
The 2017 construction completion agreement between the Vogtle Owners and Bechtel
CCR
Coal combustion residuals
Chattanooga Gas
Chattanooga Gas Company, a wholly-owned subsidiary of Southern Company Gas
COD
Commercial operation date
Contractor Settlement Agreement
The December
31, 2015 agreement between Westinghouse and the Vogtle Owners resolving disputes between the Vogtle Owners and the EPC Contractor under the Vogtle 3 and 4 Agreement
COVID-19
The novel coronavirus disease declared a pandemic by the World Health Organization and the Centers for Disease Control and Prevention in March 2020
CWIP
Construction work in progress
Dalton
City of Dalton, Georgia, an incorporated municipality in the State of Georgia, acting by and through its Board of Water, Light, and Sinking Fund Commissioners
Dalton Pipeline
A
pipeline facility in Georgia in which Southern Company Gas has a 50% undivided ownership interest
Certain costs of construction relating to Plant Vogtle Units 3 and 4 that are eligible for financing under the loan guarantee program established under Title XVII of the Energy Policy Act of 2005
EPA
U.S. Environmental Protection Agency
EPC Contractor
Westinghouse
and its affiliate, WECTEC Global Project Services Inc.; the former engineering, procurement, and construction contractor for Plant Vogtle Units 3 and 4
FERC
Federal Energy Regulatory Commission
FFB
Federal Financing Bank
Fitch
Fitch Ratings, Inc.
Form 10-K
Annual Report on Form 10-K of Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas for the year ended December 31, 2021, as applicable
GAAP
U.S.
generally accepted accounting principles
Georgia Power
Georgia Power Company
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
Integrated coal gasification combined cycle, the technology originally approved for Mississippi Power's Kemper County energy facility
IIC
Intercompany
Interchange Contract
ITAAC
Inspections, Tests, Analyses, and Acceptance Criteria, standards established by the NRC
ITC
Investment tax credit
JEA
Jacksonville Electric Authority
KWH
Kilowatt-hour
LIBOR
London Interbank Offered Rate
LIFO
Last-in, first-out
LOCOM
Lower
of weighted average cost or current market price
LTSA
Long-term service agreement
MEAG Power
Municipal Electric Authority of Georgia
Mississippi Power
Mississippi Power Company
mmBtu
Million British thermal units
Moody's
Moody's Investors Service, Inc.
MW
Megawatt
natural
gas distribution utilities
Southern Company Gas' natural gas distribution utilities (Nicor Gas, Atlanta Gas Light, Virginia Natural Gas, and Chattanooga Gas)
NCCR
Georgia Power's Nuclear Construction Cost Recovery tariff
NDR
Alabama Power's Natural Disaster Reserve
Nicor Gas
Northern Illinois Gas Company, a wholly-owned subsidiary of Southern Company Gas
NRC
U.S. Nuclear Regulatory Commission
NYMEX
New
York Mercantile Exchange, Inc.
OCI
Other comprehensive income
PennEast Pipeline
PennEast Pipeline Company, LLC, a joint venture in which Southern Company Gas has a 20% ownership interest
PEP
Mississippi Power's Performance Evaluation Plan
PowerSecure
PowerSecure, Inc., a wholly-owned subsidiary of Southern Company
PPA
Power purchase agreements, as well as, for Southern Power, contracts for differences that provide
the owner of a renewable facility a certain fixed price for the electricity sold to the grid
PSC
Public Service Commission
PTC
Production tax credit
Rate CNP
Alabama Power's Rate Certificated New Plant, consisting of Rate CNP New Plant, Rate CNP Compliance, and Rate CNP PPA
Rate ECR
Alabama Power's Rate Energy Cost Recovery
Rate RSE
Alabama Power's
Rate Stabilization and Equalization
Registrants
Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power Company, and Southern Company Gas
ROE
Return on equity
S&P
S&P Global Ratings, a division of S&P Global Inc.
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
Energy Management, L.P. and Sequent Energy Canada Corp., wholly-owned subsidiaries of Southern Company Gas through June 30, 2021
SNG
Southern Natural Gas Company, L.L.C., a pipeline system in which Southern Company Gas has a 50% ownership interest
SOFR
Secured Overnight Financing Rate
Southern Company
The Southern Company
Southern Company Gas
Southern Company Gas and its subsidiaries
Southern Company Gas Capital
Southern
Company Gas Capital Corporation, a 100%-owned subsidiary of Southern Company Gas
Southern Company power pool
The operating arrangement whereby the integrated generating resources of the traditional electric operating companies and Southern Power (excluding subsidiaries) are subject to joint commitment and dispatch in order to serve their combined load obligations
Southern Company system
Southern Company, the traditional electric operating companies, Southern Power, Southern Company Gas, SEGCO, Southern Nuclear, SCS, Southern Communications Services, Inc., PowerSecure, and other subsidiaries
Southern Nuclear
Southern Nuclear Operating
Company, Inc., a wholly-owned subsidiary of Southern Company
Southern Power
Southern Power Company and its subsidiaries
SouthStar
SouthStar Energy Services, LLC (a Marketer), a wholly-owned subsidiary of Southern Company Gas
SP Solar
SP Solar Holdings I, LP, a limited partnership indirectly owning substantially all of Southern Power's solar and battery energy storage facilities, in which Southern Power has a 67% ownership interest
SP Wind
SP Wind Holdings II, LLC, a holding company owning a portfolio of eight operating wind
facilities, in which Southern Power is the controlling partner in a tax equity arrangement
Subsidiary Registrants
Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas
Toshiba
Toshiba Corporation, the parent company of Westinghouse
traditional electric operating companies
Alabama Power, Georgia Power, and Mississippi Power
VCM
Vogtle Construction Monitoring
VIE
Variable interest
entity
Virginia Natural Gas
Virginia Natural Gas, Inc., a wholly-owned subsidiary of Southern Company Gas
Vogtle 3 and 4 Agreement
Agreement entered into with the EPC Contractor in 2008 by Georgia Power, acting for itself and as agent for the Vogtle Owners, and rejected in bankruptcy in July 2017, pursuant to which the EPC Contractor agreed to design, engineer, procure, construct, and test Plant Vogtle Units 3 and 4
Vogtle Owners
Georgia Power, 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
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION
This Quarterly Report on Form 10-Q contains forward-looking statements. Forward-looking statements include, among other things, statements concerning the potential and expected effects of the continued COVID-19 pandemic, regulated rates, the strategic goals for the business, customer and sales growth, economic conditions, cost recovery and other rate actions, projected equity ratios, current and proposed environmental regulations and related compliance plans and estimated expenditures, pending or potential litigation matters, access to sources of capital, financing activities, completion dates and costs
of construction projects, matters related to the abandonment of the Kemper IGCC, completion of announced acquisitions, filings with state and federal regulatory authorities, and estimated construction plans and expenditures. In some cases, forward-looking statements can be identified by terminology such as "may,""will,""could,""would,""should,""expects,""plans,""anticipates,""believes,""estimates,""projects,""predicts,""potential," or "continue" or the negative of these terms or other similar terminology. There are various factors that could cause actual results to differ materially from those suggested by the forward-looking statements; accordingly, there can be no assurance that such indicated results will be realized. These factors include:
•the impact of recent
and future federal and state regulatory changes, including tax, environmental, and other laws and regulations to which Southern Company and its subsidiaries are subject, as well as changes in application of existing laws and regulations;
•the potential effects of the continued COVID-19 pandemic, including, but not limited to, those described in Item 1A "Risk Factors" of the Form 10-K;
•the extent and timing of costs and legal requirements related to CCR;
•current and future litigation or regulatory investigations, proceedings, or inquiries, including litigation and other disputes related to the Kemper County energy facility;
•the effects, extent, and timing of the entry of additional competition
in the markets in which Southern Company's subsidiaries operate, including from the development and deployment of alternative energy sources;
•variations in demand for electricity and natural gas;
•available sources and costs of natural gas and other fuels and commodities;
•the ability to complete necessary or desirable pipeline expansion or infrastructure projects, limits on pipeline capacity, and operational interruptions to natural gas distribution and transmission activities;
•transmission constraints;
•effects of inflation;
•the ability to control costs and avoid
cost and schedule overruns during the development, construction, and operation of facilities or other projects, including Plant Vogtle Units 3 and 4 (which includes components based on new technology that only within the last few years began initial operation in the global nuclear industry at this scale) and Plant Barry Unit 8, due to current and/or future challenges which include, but are not limited to, changes in labor costs, availability, and productivity; challenges with management of contractors or vendors; subcontractor performance; adverse weather conditions; shortages, delays, increased costs, or inconsistent quality of equipment, materials, and labor; contractor or supplier delay; delays due to judicial or regulatory action; nonperformance under construction, operating, or other agreements; operational readiness, including specialized operator training and required site safety programs; engineering or design problems or any remediation related thereto; design
and other licensing-based compliance matters, including, for nuclear units, inspections and the timely submittal by Southern Nuclear of the ITAAC documentation for each unit and the related investigations, reviews, and approvals by the NRC necessary to support NRC authorization to load fuel; challenges with start-up activities, including major equipment failure, or system integration; and/or operational performance; and challenges related to the COVID-19 pandemic;
•the ability to overcome or mitigate the current challenges at Plant Vogtle Units 3 and 4, as described in Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" in Item 1 herein, that could further impact the cost and schedule for the project;
•legal proceedings and regulatory approvals and actions related to construction projects,
such as Plant Vogtle Units 3 and 4 and Plant Barry Unit 8, including PSC approvals and FERC and NRC actions;
•under certain specified circumstances, a decision by holders of more than 10% of the ownership interests of Plant Vogtle Units 3 and 4 not to proceed with construction and the ability of other Vogtle Owners to tender a portion of their ownership interests to Georgia Power following certain construction cost increases;
CAUTIONARY
STATEMENT REGARDING FORWARD-LOOKING INFORMATION
(continued)
•in the event Georgia Power becomes obligated to provide funding to MEAG Power with respect to the portion of MEAG Power's ownership interest in Plant Vogtle Units 3 and 4 involving JEA, any inability of Georgia Power to receive repayment of such funding;
•the ability to construct facilities in accordance with the requirements of permits and licenses (including satisfaction of NRC requirements), to satisfy any environmental performance standards and the requirements of tax credits and other incentives, and to integrate facilities into the Southern Company system upon completion of construction;
•investment performance of the employee and retiree benefit plans and
nuclear decommissioning trust funds;
•advances in technology, including the pace and extent of development of low- to no-carbon energy technologies and negative carbon concepts;
•performance of counterparties under ongoing renewable energy partnerships and development agreements;
•state and federal rate regulations and the impact of pending and future rate cases and negotiations, including rate actions relating to ROE, equity ratios, additional generating capacity, and fuel and other cost recovery mechanisms;
•the ability to successfully operate the traditional electric operating companies' and SEGCO's generation, transmission, and distribution facilities, Southern Power's generation facilities, and
Southern Company Gas' natural gas distribution and storage facilities and the successful performance of necessary corporate functions;
•the inherent risks involved in operating and constructing nuclear generating facilities;
•the inherent risks involved in transporting and storing natural gas;
•the performance of projects undertaken by the non-utility businesses and the success of efforts to invest in and develop new opportunities;
•internal restructuring or other restructuring options that may be pursued;
•potential business strategies, including acquisitions or dispositions of assets or businesses, which cannot be assured to be completed
or beneficial to Southern Company or its subsidiaries;
•the ability of counterparties of Southern Company and its subsidiaries to make payments as and when due and to perform as required;
•the ability to obtain new short- and long-term contracts with wholesale customers;
•the direct or indirect effect on the Southern Company system's business resulting from cyber intrusion or physical attack and the threat of physical attacks;
•interest rate fluctuations and financial market conditions and the results of financing efforts;
•access to capital markets and other financing sources;
•changes
in Southern Company's and any of its subsidiaries' credit ratings;
•the replacement of LIBOR with an alternative reference rate;
•the ability of the traditional electric operating companies to obtain additional generating capacity (or sell excess generating capacity) at competitive prices;
•catastrophic events such as fires, earthquakes, explosions, floods, tornadoes, hurricanes and other storms, droughts, pandemic health events, political unrest, wars, or other similar occurrences;
•the direct or indirect effects on the Southern Company system's business resulting from incidents affecting the U.S. electric grid, natural gas pipeline infrastructure, or operation of generating or storage resources;
•impairments
of goodwill or long-lived assets;
•the effect of accounting pronouncements issued periodically by standard-setting bodies; and
•other factors discussed elsewhere herein and in other reports (including the Form 10-K) filed by the Registrants from time to time with the SEC.
The Registrants expressly disclaim any obligation to update any forward-looking statements.
INDEX TO APPLICABLE NOTES TO FINANCIAL STATEMENTS BY REGISTRANT
The following unaudited notes to the condensed financial statements are a combined presentation;
however, information contained herein relating to any individual Registrant is filed by such Registrant on its own behalf and each Registrant makes no representation as to information related to the other Registrants. The list below indicates the Registrants to which each footnote applies.
iThe
condensed quarterly financial statements of each Registrant included herein have been prepared by such Registrant, without audit, pursuant to the rules and regulations of the SEC. The Condensed Balance Sheets at December 31, 2021 have been derived from the audited financial statements of each Registrant. In the opinion of each Registrant's management, the information regarding such Registrant furnished herein reflects all adjustments, which, except as otherwise disclosed, are of a normal recurring nature, necessary to present fairly the results of operations for the periods ended March 31, 2022 and 2021. Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations, although each Registrant
believes that the disclosures regarding such Registrant are adequate to make the information presented not misleading. Disclosures which would substantially duplicate the disclosures in the Form 10-K and details which have not changed significantly in amount or composition since the filing of the Form 10-K are generally omitted from this Quarterly Report on Form 10-Q unless specifically required by GAAP. Therefore, these Condensed Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the Form 10-K. Due to the seasonal variations in the demand for energy and other factors, operating results for the periods presented are not necessarily indicative of the operating results to be expected for the full year.
iCertain
prior year data presented in the financial statements have been reclassified to conform to the current year presentation. These reclassifications had no impact on the overall results of operations, financial position, or cash flows of any Registrant.
iGoodwill
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.
(a)Includes
$i5 million recorded as a reduction to operating revenues.
(b)Recorded as a reduction to operating revenues.
/
Cash, Cash Equivalents, and Restricted Cash
ii
The
following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amount shown in the condensed statements of cash flows for the applicable Registrants:
Total
cash, cash equivalents, and restricted cash(b)
$
i1,673
$
i1,829
$
i139
$
i135
$
i33
$
i48
(a)For
Southern Power, restricted cash reflects $i9 million and $i10 million at March 31, 2022 and December
31, 2021, respectively, held to fund estimated construction completion costs at the Deuel Harvest wind facility and $i19 million at December 31, 2021 related to tax equity contributions restricted until the Garland battery energy storage facility achieved final contracted capacity. For Southern Company Gas, reflects restricted cash held as collateral for workers' compensation, life insurance, and long-term disability insurance.
(b)Total may
not add due to rounding.
//i
Natural Gas for Sale
With the exception of Nicor Gas, Southern Company Gas records natural gas inventories on a WACOG basis. For any declines in market prices below the WACOG considered to be other than temporary, an
adjustment is recorded to reduce the value of natural gas inventories to market value. Nicor Gas' natural gas inventory is carried at cost on a LIFO basis. Inventory decrements occurring during the year that are restored prior to year end are charged to cost of natural gas at the estimated annual replacement cost. Inventory decrements that are not restored prior to year end are charged to cost of natural gas at the actual LIFO cost of the inventory layers liquidated.
Southern Company Gas recorded no material adjustments to natural gas inventories for either period presented. Nicor Gas' inventory decrement at March 31, 2022 is expected to be restored prior to year end.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Depreciation and Amortization
See Note 5 to the financial statements under "Depreciation and Amortization – Southern Power" in Item 8 of the Form 10-K for additional information.
Effective January 1, 2022, Southern Power revised the depreciable lives of its wind generating facilities from up to i30
years to up to i35 years. This revision resulted in an immaterial decrease in depreciation for the three months ended March 31, 2022 and is expected to result in an immaterial decrease in annual depreciation for 2022.
(B) iREGULATORY
MATTERS
See Note 2 to the financial statements in Item 8 of the Form 10-K for additional information relating to regulatory matters.
i
The recovery balances for certain retail regulatory clauses of the traditional electric operating companies and Southern Company Gas at March 31, 2022 and December 31, 2021 were as follows:
(*)In
accordance with an Alabama PSC order issued on February 1, 2022, Alabama Power applied $i126 million of its 2021 Rate RSE refund to reduce the Rate ECR under recovered balance.
/
Alabama Power
Certificate
of Convenience and Necessity
On March 25, 2022, the FERC approved Alabama Power's acquisition of the Calhoun Generating Station, which is expected to be completed by September 30, 2022. The completion of the acquisition remains subject to approval by the Alabama PSC. The ultimate outcome of this matter cannot be determined at this time.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Georgia Power
Rate Plan
In 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, in October 2021, the Georgia Court of Appeals affirmed the Superior Court of Fulton County's order. In December 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 to the financial statements in Item 8 of the Form
10-K for additional information regarding Georgia Power's AROs.
Integrated Resource Plan
In light of the ongoing supply chain challenges in the solar industry, Georgia Power amended the i970 MWs of utility-scale PPAs authorized in its 2019 Integrated Resource Plan to extend by ione
year the in-service dates for solar generation resources to the end of 2024.
Nuclear Construction
In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4, in which Georgia Power holds a i45.7% ownership interest. In 2012, the NRC issued the related combined construction and operating licenses, which allowed full construction
of the itwo AP1000 nuclear units (with electric generating capacity of approximately i1,100
MWs each) and related facilities to begin. Until March 2017, construction on Plant Vogtle Units 3 and 4 continued under the Vogtle 3 and 4 Agreement, which was a substantially fixed price agreement.
In connection with the EPC Contractor's bankruptcy filing in March 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into several transitional arrangements to allow construction to continue. In July 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into the Vogtle Services Agreement, whereby Westinghouse provides facility design and engineering services, procurement and technical support, and staff augmentation on a time and materials cost basis. The Vogtle Services Agreement provides that it will continue until the start-up and testing of Plant Vogtle Units 3 and 4 are complete and electricity is generated and sold from both units. The Vogtle Services
Agreement is terminable by the Vogtle Owners upon i30 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 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K for information on the Amended and Restated Loan Guarantee Agreement, including applicable covenants, events of default, and mandatory prepayment
events.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Cost and Schedule
i
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:
(a)Includes
approximately $i590 million of costs that are not shared with the other Vogtle Owners and approximately $i440 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 $i377 million, of which $i221
million had been accrued through March 31, 2022.
(b)Net of $i1.7 billion received from Toshiba under the Guarantee Settlement Agreement and approximately $i188
million in related customer refunds.
/
Georgia Power estimates that its financing costs for construction of Plant Vogtle Units 3 and 4 will total approximately $i3.4 billion, of which $i3.0
billion had been incurred through March 31, 2022.
As part of its ongoing processes, Southern Nuclear continues to evaluate cost and schedule forecasts on a regular basis to incorporate current information available, particularly in the areas of engineering support, commodity installation, system turnovers and related test results, and workforce statistics. Southern Nuclear establishes aggressive target values for monthly construction production and system turnover activities, which are reflected in the site work plans.
Since March 2020, the number of active COVID-19 cases at the site has fluctuated consistent with the surrounding area and impacted productivity levels and pace of activity completion, with the site experiencing peaks in the number of active cases in January 2021, August 2021, and January 2022. Georgia Power estimates
the productivity impacts of the COVID-19 pandemic have consumed approximately three to ifour months of schedule margin previously embedded in the site work plan for Unit 3 and Unit 4. As of March 31, 2022, Georgia Power's proportionate share of the estimated incremental cost associated with COVID-19 mitigation actions and impacts on construction productivity is estimated to be between $i160
million and $i200 million and is included in the total project capital cost forecast. The continuing effects of the COVID-19 pandemic could further disrupt or delay construction and testing activities at Plant Vogtle Units 3 and 4.
Fuel load for Unit 3 is projected during the third quarter or the fourth quarter 2022 with an in-service date projected during the fourth quarter 2022 or the first quarter 2023. Unit 3's projected schedule primarily depends on improvements in overall construction productivity and
production levels, the volume and completion of construction remediation work, completion of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, the pace of system and area turnovers, and the progression of startup and other testing. An in-service date during the third quarter or the fourth quarter 2023 for Unit 4 is projected. Unit 4's projected schedule primarily depends on overall construction productivity and production levels improving as well as appropriate levels of craft laborers, particularly electricians and pipefitters, being added and maintained. Any further delays could result in later in-service dates.
During the first quarter 2022, established construction contingency totaling $i43
million was assigned to the base capital cost forecast for costs primarily associated with construction productivity, the pace of system turnovers, and support resources for Units 3 and 4.
As Unit 3 completes system turnover from construction and moves to testing and transition to operations, ongoing and potential future challenges include construction productivity, completion of construction remediation work,
NOTES
TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
completion of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, and final component and pre-operational tests. As Unit 4 progresses through construction and continues to transition into testing, ongoing and potential future challenges include the pace and quality of electrical installation; availability of craft and supervisory resources, including the temporary diversion of such resources to support Unit 3 construction efforts; the pace of work package closures and system turnovers; and the timeframe and duration of hot functional and other testing. As construction, including subcontract work, continues on both Units 3 and 4, ongoing or future challenges include management of contractors and vendors; subcontractor performance; supervision of craft
labor and related productivity, particularly in the installation of electrical, mechanical, and instrumentation and controls commodities, ability to attract and retain craft labor, and/or related cost escalation; and procurement and related installation. New challenges may arise, particularly as Units 3 and 4 move into initial testing and start-up, which may result in required engineering changes or remediation related to plant systems, structures, or components (some of which are based on new technology that only within the last few years began initial operation in the global nuclear industry at this scale). The ongoing and potential future challenges described above may change the projected schedule and estimated cost.
There have been technical and procedural challenges to the construction and licensing of Plant Vogtle Units 3 and 4 at the federal and state level and additional challenges may arise. In addition, certain license
amendment requests have been filed and approved or are pending before the NRC. Processes are in place that are designed to ensure compliance with the requirements specified in the Westinghouse Design Control Document and the combined construction and operating licenses, including inspections by Southern Nuclear and the NRC that occur throughout construction. In connection with the additional construction remediation work described above, Southern Nuclear reviewed the project's construction quality programs and, where needed, is implementing improvement plans consistent with these processes. On March 25, 2022, the NRC completed its follow-up inspection related to the November 2021 final significance report on its special inspection to review the root cause of this additional construction remediation work and the corresponding corrective action plans. The NRC closed the two white findings identified in November 2021 and
returned Vogtle Unit 3 to the NRC's baseline inspection program.
Various design and other licensing-based compliance matters, including the timely submittal by Southern Nuclear of the ITAAC documentation for each unit and the related reviews and approvals by the NRC necessary to support NRC authorization to load fuel, have arisen or may arise, which may result in additional license amendments or require other resolution. If any license amendment requests or other licensing-based compliance issues, including inspections and ITAACs, are not resolved in a timely manner, there may be delays in the project schedule that could result in increased costs.
The ultimate outcome of these matters cannot be determined at this time. However, any extension of the in-service date beyond the first quarter 2023 for Unit 3 or the fourth quarter 2023 for Unit 4, including the current level of cost sharing
described below, is estimated to result in additional base capital costs for Georgia Power of up to $i60 million per month for Unit 3 and $i40
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 i90% 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
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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 $i300
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 $i8.4
billion in the nineteenth VCM plus $i800 million; (ii) Georgia Power will be responsible for i55.7% of actual qualifying construction
costs between $i800 million and $i1.6 billion over the EAC in the nineteenth VCM (resulting in $i80
million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for i44.3% of such costs pro rata in accordance with their respective ownership interests; and (iii) Georgia Power will be responsible for i65.7%
of qualifying construction costs between $i1.6 billion and $i2.1 billion over the EAC in the nineteenth VCM (resulting
in a further $i100 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for i34.3% 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 $i2.1 billion, each of the other Vogtle Owners will have a one-time option at the time the project budget cost forecast is so revised to tender a portion of its ownership interest to Georgia Power in exchange for Georgia Power's agreement to pay i100%
of such Vogtle Owner's remaining share of total construction costs in excess of the EAC in the nineteenth VCM plus $i2.1 billion.
For purposes of the foregoing provisions, qualifying construction costs will not include costs (i) resulting from force majeure events, including epidemics and quarantines, governmental actions or inactions (or significant delays associated with issuance of such actions) that affect the licensing, completion, start-up, operations, or financing of Plant Vogtle Units 3 and
4, administrative proceedings or litigation regarding ITAAC or other regulatory challenges to commencement of operation of Plant Vogtle Units 3 and 4, and changes in laws or regulations governing Plant Vogtle Units 3 and 4, (ii) legal fees and legal expenses incurred due to litigation with contractors or subcontractors that are not subsidiaries or affiliates of Southern Company, and (iii) additional costs caused by requests from the Vogtle Owners other than Georgia Power, except for the exercise of a right to vote granted under the Vogtle Joint Ownership Agreements, that increase costs by $i100,000
or more.
In addition, pursuant to the Global Amendments, the holders of at least i90% 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 i6% of costs during any isix-month
VCM reporting period that are disallowed by the Georgia PSC for
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
recovery, or for which Georgia Power elects not to seek cost recovery, through retail rates; and (iv) an incremental extension of ione
year or more from the seventeenth VCM report estimated in-service dates of November 2021 and November 2022 for Units 3 and 4, respectively. The schedule extension announced in February 2022 triggered the requirement for a vote to continue construction. Effective February 25, 2022, all of the Vogtle Owners had voted to continue construction.
Georgia Power and the other Vogtle Owners do not agree on either the starting dollar amount for the determination of cost increases subject to the cost-sharing and tender provisions of the Global Amendments or the extent to which COVID-19-related costs impact those provisions. Based on the definition in the Global Amendments, Georgia Power believes the starting dollar amount is $i18.38 billion
and the current project capital cost forecast exceeds the cost-sharing provision threshold, but not the tender provision threshold. The other Vogtle Owners have notified Georgia Power that they believe the current project capital cost forecast exceeds the cost-sharing thresholds and triggers the tender provisions under the Global Amendments. Georgia Power recorded a pre-tax charge to income in the fourth quarter 2021 of approximately $i440 million ($i328
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 $i460 million associated with these provisions based on the current project capital cost forecast. Georgia Power's incremental charges associated with these provisions, which relate to the other Vogtle Owners' share of costs, will not be recovered from retail customers. In October 2021, Georgia Power and the other Vogtle Owners
entered into an agreement 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 i45.7%; 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 i100% 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 $i4.418 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 $i4.418
billion. At March 31, 2022, Georgia Power had recovered approximately $i2.8 billion of financing costs. Financing costs related to capital costs above $i4.418
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 $i7.3 billion) and not requested for rate recovery. In November 2021, the Georgia PSC approved Georgia Power's request to decrease the NCCR tariff by $i78
million annually, effective January 1, 2022.
Georgia Power is required to file semi-annual VCM reports with the Georgia PSC by February 28 and August 31 of each year. In 2013, in connection with the eighth VCM report, the Georgia PSC approved a stipulation between Georgia Power and the staff of the Georgia PSC to waive the requirement to amend the Plant Vogtle Units 3 and 4 certificate in accordance with the 2009 certification order until the completion of Plant Vogtle Unit 3, or earlier if deemed appropriate by the Georgia PSC and Georgia Power.
In 2016, the Georgia PSC voted to approve a settlement agreement (Vogtle Cost Settlement Agreement) resolving certain prudency matters in connection with the fifteenth VCM report. In December 2017, the Georgia PSC voted to approve (and issued its related order on January
11, 2018) Georgia Power's seventeenth VCM report and modified the Vogtle Cost Settlement Agreement. The Vogtle Cost Settlement Agreement, as modified by the January 11,
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
2018 order, resolved the following regulatory matters related to Plant Vogtle Units 3 and 4: (i) none
of the $i3.3 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 $i0.3
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 $i5.68 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 $i5.68
billion were prudent, and (c) a revised capital cost forecast of $i7.3 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 i10.95% (the ROE rate setting point authorized by the Georgia PSC in the 2013 alternate rate plan) to i10.00%
effective January 1, 2016, (b) from i10.00% to i8.30%, effective January
1, 2020, and (c) from i8.30% to i5.30%, 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 i10.00% to Georgia Power's average cost of long-term debt, effective January 1, 2018; and (ix) agreed that effective the first month after Unit 3 reaches commercial operation, retail base rates would be adjusted to include the costs related to Unit 3 and common facilities deemed prudent in the Vogtle Cost Settlement Agreement (see Note 2 to
the financial statements under "Georgia Power – Plant Vogtle Unit 3 and Common Facilities Rate Proceeding" in Item 8 of the Form 10-K for additional information). The January 11, 2018 order also stated that if Plant Vogtle Units 3 and 4 are not commercially operational by June 1, 2021 and June 1, 2022, respectively, the ROE used to calculate the NCCR tariff will be further reduced by i10
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 $i270 million in 2021 and are estimated to have negative earnings impacts of approximately $i300
million and $i265 million in 2022 and 2023, respectively. In its January 11, 2018 order, the Georgia PSC also stated if other conditions change and assumptions upon which Georgia Power's seventeenth VCM report are based do not materialize, the Georgia PSC reserved the right to reconsider the decision to continue construction.
In the August 2021 order approving the twenty-fourth VCM report, the Georgia PSC approved a stipulation addressing
the following matters: (i) beginning with its twenty-fifth VCM report, Georgia Power will continue to report to the Georgia PSC all costs incurred during the period for review and will request for approval costs up to the $i7.3 billion determined to be reasonable in the Georgia PSC's seventeenth VCM order and (ii) Georgia Power will not seek rate recovery of the $i0.7
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 $i7.3 billion for inclusion in rate base at a later time, but no earlier than the prudence review contemplated by the seventeenth VCM order described previously.
The Georgia PSC has approved i25
VCM reports covering periods through June 30, 2021. These reports reflect total construction capital costs incurred of $i7.9 billion (net of $i1.7
billion of payments received under the Guarantee Settlement Agreement and approximately $i188 million in related customer refunds), of which the Georgia PSC has verified and approved $i7.3
billion as described above. Georgia Power filed its twenty-sixth VCM report with the Georgia PSC on February 17, 2022, reflecting $i584 million of additional construction capital costs incurred through December 31, 2021 and the total capital cost forecast described above.
The ultimate outcome of these matters cannot be determined at this time.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Mississippi Power
Performance Evaluation Plan
On March 15, 2022, Mississippi Power submitted its annual retail PEP filing for 2022 to the Mississippi PSC, which requested a i1.9%,
or approximately $i18 million, annual increase in revenues, primarily due to increases in investment, operations and maintenance expenses, and depreciation and amortization. In accordance with the PEP rate schedule, the rate increase became effective with the first billing cycle of April 2022, subject to refund. The related proceedings are expected to conclude in summer 2022; however, the ultimate outcome of this matter cannot be determined at this time.
Ad Valorem Tax Adjustment
On
April 13, 2022, Mississippi Power submitted its annual ad valorem tax adjustment filing for 2022, which requested a $i5 million annual increase in revenues. The ultimate outcome of this matter cannot be determined at this time.
Southern Company Gas
Infrastructure
Replacement Programs and Capital Projects
i
Capital expenditures incurred under specific infrastructure replacement programs and capital projects during the first three months of 2022 were as follows:
See Note 3 to the financial statements in Item 8 of the Form 10-K for information relating to various lawsuits and other contingencies.
General Litigation Matters
The Registrants are involved in various matters being litigated and regulatory matters. The ultimate outcome of such pending or potential litigation
or regulatory matters against each Registrant and any subsidiaries cannot be determined at this time; however, for current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, arising from such current proceedings would have a material effect on such Registrant's financial statements.
The Registrants believe the pending legal challenges discussed below have no merit; however, the ultimate outcome of these matters cannot be determined at this time.
Southern Company
In February 2017, Jean Vineyard and Judy Mesirov each filed a shareholder derivative lawsuit in the U.S. District Court for the Northern District of Georgia. Each of these lawsuits 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 itwo shareholder derivative lawsuits were consolidated in the U.S. District Court for the Northern District of
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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 actions. On March 11, 2022, the U.S. District Court for the Northern District of Georgia entered an order preliminarily approving the settlement. The proposed settlement consists of an aggregate payment by Southern Company's insurers of approximately $i4.5 million
for attorneys' fees and expenses, as well as adoption of various corporate governance reforms by Southern Company. The terms of the proposed settlement and the corporate governance reforms remain subject to final approval by the court.
Georgia Power
In 2011, plaintiffs filed a putative class action against Georgia Power in the Superior Court of Fulton County, Georgia alleging that Georgia Power's collection in rates of amounts for municipal franchise fees (which fees are paid to municipalities) exceeded the amounts allowed in orders of the Georgia PSC and alleging certain state law claims. This case has been ruled upon and appealed numerous times over the last several years. In 2019, the Georgia PSC issued an order that found Georgia Power has appropriately implemented
the municipal franchise fee schedule. In March 2021, the Superior Court of Fulton County granted class certification and Georgia Power's motion for summary judgment and the plaintiffs filed a notice of appeal. In April 2021, Georgia Power filed a notice of cross appeal on the issue of class certification. In December 2021, the Georgia Court of Appeals affirmed the Superior Court's ruling that granted summary judgment to Georgia Power and dismissed Georgia Power's cross appeal on the issue of class certification as moot. Also in December 2021, the plaintiffs filed a petition for writ of certiorari to the Georgia Supreme Court. The amount of any possible losses cannot be estimated at this time because, among other factors, it is unknown whether any losses would be subject to recovery from any municipalities.
In July 2020, a group of individual plaintiffs filed a complaint in the Superior Court of Fulton County, Georgia against
Georgia Power alleging that releases from Plant Scherer have impacted groundwater, surface water, and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages, a medical monitoring fund, and injunctive relief. Georgia Power has filed multiple motions to dismiss the complaint. In October 2021, ithree additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power alleging that releases from Plant Scherer have
impacted groundwater and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages. In November 2021, Georgia Power filed a notice to remove the ithree cases pending in the Superior Court of Monroe County, Georgia to the U.S. District Court for the Middle District of Georgia. On February 7, 2022, ifour
additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power seeking damages for alleged personal injuries or property damage. On March 9, 2022, Georgia Power filed a notice to remove the ifour cases pending in the Superior Court of Monroe
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
County, Georgia to the U.S. District Court for the Middle District of Georgia. The amount of any possible losses from these matters cannot be estimated at this time.
Mississippi Power
In 2018, Ray C. Turnage and i10
other individual plaintiffs filed a putative class action complaint against Mississippi Power and the ithree 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 ifour
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 $i23.5
million in the refund process by applying an incorrect interest rate. The plaintiffs seek to recover, on behalf of themselves and their putative class, actual damages, punitive damages, pre-judgment interest, post-judgment interest, attorney's fees, and costs. The district court dismissed the amended complaint; however, in March 2020, the plaintiffs filed a motion seeking to name the new members of the Mississippi PSC, the Mississippi Development Authority, and Southern Company as additional defendants and add a cause of action against all defendants based on a dormant commerce clause theory under the U.S. Constitution. In July 2020, the plaintiffs filed a motion for leave to file a third amended complaint, which included the same federal claims as the proposed second amended complaint, as well as several additional state law claims based on the allegation that Mississippi Power failed to disclose the annual percentage rate of interest applicable to refunds. In November
2020, the district court denied each of the plaintiffs' pending motions and entered final judgment in favor of Mississippi Power. In January 2021, the district court denied further motions by the plaintiffs to vacate the judgment and to file a revised second amended complaint. In February 2021, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit. On March 21, 2022, the U.S. Court of Appeals for the Fifth Circuit issued an opinion affirming the dismissal of the claims against the Mississippi PSC defendants but reversing the dismissal of the claims against Mississippi Power. The appellate court remanded the case to the U.S. District Court for the Southern District of Mississippi for further proceedings. The appellate court's decision is not final until the opportunity for rehearing en banc is resolved. An adverse outcome in this proceeding could have a material impact on Mississippi
Power's financial statements.
Environmental Remediation
The Southern Company system must comply with environmental laws and regulations governing the handling and disposal of waste and releases of hazardous substances. Under these various laws and regulations, the Southern Company system could incur substantial costs to clean up affected sites. The traditional electric operating companies and the natural gas distribution utilities in Illinois and Georgia have each received authority from their respective state PSCs or other applicable state regulatory agencies to recover approved environmental remediation costs through regulatory mechanisms. These regulatory mechanisms are adjusted annually or as necessary within limits approved by the state PSCs or other applicable
state regulatory agencies.
Georgia Power's environmental remediation liability was $i16 million and $i17
million at March 31, 2022 and December 31, 2021, respectively. Georgia Power has been designated or identified as a potentially responsible party at sites governed by the Georgia Hazardous Site Response Act and/or by the federal Comprehensive Environmental Response, Compensation, and Liability Act, and assessment and potential cleanup of such sites is expected.
Southern Company Gas' environmental remediation liability was $ii249/
million at both March 31, 2022 and December 31, 2021 based on the estimated cost of environmental investigation and remediation associated with known former manufactured gas plant operating sites.
The ultimate outcome of these matters cannot be determined at this time; however, as a result of the regulatory treatment for environmental remediation expenses described above, the final disposition of these matters is not expected to have a material impact on the financial statements of the applicable Registrants.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
(D) iREVENUE FROM CONTRACTS WITH CUSTOMERS AND LEASE INCOME
Revenue from Contracts with Customers
The
Registrants generate revenues from a variety of sources, some of which are not accounted for as revenue from contracts with customers, such as leases, derivatives, and certain cost recovery mechanisms. See Note 1 to the financial statements under "Revenues" in Item 8 of the Form 10-K for additional information on the revenue policies of the Registrants. See "Lease Income" herein and Note (J) for additional information on revenue accounted for under lease and derivative accounting guidance, respectively.
i
The following
table disaggregates revenue from contracts with customers for the three months ended March 31, 2022 and 2021:
(a)Other
revenue sources relate to revenues from customers accounted for as derivatives and leases, alternative revenue programs at Southern Company Gas, and cost recovery mechanisms and revenues that meet other scope exceptions for revenues from contracts with customers at the traditional electric operating companies.
(b)Other adjustments relate to the cost of Southern Company Gas' energy and risk management activities. Wholesale gas services revenues are presented net of the related costs of those activities on the statement of income. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (L) under "Southern Company Gas" for information on the sale of Sequent and components of wholesale gas services' operating revenues, respectively.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Contract Balances
i
The following table reflects the closing balances of receivables, contract assets, and contract liabilities related
to revenues from contracts with customers at March 31, 2022 and December 31, 2021:
At
March 31, 2022 and December 31, 2021, Georgia Power had contract assets primarily related to retail customer fixed bill programs, where the payment is contingent upon Georgia Power's continued performance and the customer's continued participation in the program over a one-year contract term, and unregulated service agreements, where payment is contingent on project completion. Contract liabilities for Georgia Power relate to cash collections recognized in advance of revenue for unregulated service agreements. Southern Company's unregulated distributed generation business had $i47
million and $i50 million of contract assets and $i54 million and $i39
million of contract liabilities at March 31, 2022 and December 31, 2021, respectively, for outstanding performance obligations.
Revenues recognized in the three months ended March 31, 2022, which were included in contract liabilities at December 31, 2021, were immaterial for all Registrants.
Remaining Performance Obligations
The Subsidiary Registrants have long-term contracts with customers in which revenues are recognized as performance obligations are satisfied over the contract term. For the traditional electric operating companies and Southern Power, these contracts primarily relate to PPAs whereby electricity and generation capacity are
provided to a customer. The revenue recognized for the delivery of electricity is variable; however, certain PPAs include a fixed payment for fixed generation capacity over the term of the contract. Southern Company's unregulated distributed generation business also has partially satisfied performance obligations related to certain fixed price contracts. iRevenues from contracts with customers related to these performance obligations remaining at March 31,
2022 are expected to be recognized as follows:
2022 (remaining)
2023
2024
2025
2026
Thereafter
(in
millions)
Southern Company
$
i529
$
i459
$
i351
$
i321
$
i307
$
i2,345
Alabama
Power
i24
i24
i7
i5
i—
i—
Georgia
Power
i55
i55
i26
i22
i11
i21
Southern
Power
i252
i294
i310
i294
i299
i2,339
Revenue
expected to be recognized for performance obligations remaining at March 31, 2022 was immaterial for Mississippi Power and Southern Company Gas.
Lease income - interest income on sales-type leases
$
i3
$
i—
$
i—
$
i3
$
i—
$
i—
Lease
income - operating leases
i55
i21
i10
i—
i21
i9
Variable
lease income
i84
i—
i—
i—
i90
i—
Total
lease income
$
i142
$
i21
$
i10
$
i3
$
i111
$
i9
/
Lease
payments received under tolling arrangements and PPAs consist of either scheduled payments or variable payments based on the amount of energy produced by the underlying electric generating units. Lease income for Alabama Power and Southern Power is included in wholesale revenues.
(E) iCONSOLIDATED ENTITIES AND EQUITY METHOD INVESTMENTS
See Note 7 to the financial statements
in Item 8 of the Form 10-K for additional information.
Southern Power
Variable Interest Entities
Southern Power has certain subsidiaries that are determined to be VIEs. Southern Power is considered the primary beneficiary of these VIEs because it controls the most significant activities of the VIEs, including operating and maintaining the respective assets, and has the obligation to absorb expected losses of these VIEs to the extent of its equity interests.
SP Solar and SP Wind
At March 31, 2022 and December 31, 2021, SP Solar had total
assets of $i6.0 billion and $i6.1 billion, respectively, total liabilities of $i407
million and $i408 million, respectively, and noncontrolling interests of $ii1.1/
billion. Cash distributions from SP Solar are allocated i67% to Southern Power and i33%
to Global Atlantic in accordance with their partnership interest percentage. Under the terms of the limited partnership agreement, distributions without limited partner consent are limited to available cash and SP Solar is obligated to distribute all such available cash to its partners each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves.
At March 31, 2022 and December 31, 2021, SP Wind had total assets of $ii2.3/
billion, total liabilities of $i180 million and $i130 million, respectively, and noncontrolling interests of $ii41/
million. Under the terms of the limited liability agreement, distributions without Class A member consent are limited to available cash and SP Wind is obligated to distribute all such available cash to its members each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves. Cash distributions from SP Wind are generally allocated i60% to Southern Power and i40%
to the ithree financial investors in accordance with the limited liability agreement.
NOTES
TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Southern Power consolidates both SP Solar and SP Wind, as the primary beneficiary, since it controls the most significant activities of each entity, including operating and maintaining their assets. Certain transfers and sales of the assets in the VIEs are subject to partner consent and the liabilities are non-recourse to the general credit of Southern Power. Liabilities consist of customary working capital items and do not include any long-term debt.
Other Variable Interest Entities
Southern Power has other consolidated VIEs that relate to certain subsidiaries that have either sold noncontrolling interests to tax equity investors or acquired less than a 100% interest from facility developers. These entities are considered VIEs because the
arrangements are structured similar to a limited partnership and the noncontrolling members do not have substantive kick-out rights.
At March 31, 2022 and December 31, 2021, the other VIEs had total assets of $i1.8 billion and $i1.9
billion, respectively, total liabilities of $i248 million and $i263 million, respectively, and noncontrolling interests of $i876
million and $i886 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 March 31, 2022 and December 31, 2021, Southern Power had equity method investments in wind and battery energy
storage projects totaling $i56 million and $i86 million, respectively. Earnings (loss) from these investments were immaterial for both periods presented. During the first quarter 2022, Southern Power
sold an equity method investment in a wind project and received proceeds of $i31 million. The gain associated with the transaction was immaterial.
Southern Company Gas
Equity Method Investments
i
The
carrying amounts of Southern Company Gas' equity method investments at March 31, 2022 and December 31, 2021 and related earnings from those investments for the three months ended March 31, 2022 and 2021 were as follows:
NOTES TO THE CONDENSED FINANCIAL STATEMENTS
(Continued)
(UNAUDITED)
(F) iFINANCING
Bank Credit Arrangements
See Note 8 to the financial statements under "Bank Credit Arrangements" in Item 8 of the Form 10-K for additional information.
i
At
March 31, 2022, committed credit arrangements with banks were as follows:
Expires
Company
2022
2024
2025
2026
Total
Unused
Expires
within One Year
(in millions)
Southern Company parent
$
i—
$
i—
$
i—
$
i2,000
$
i2,000
$
i1,998
$
i—
Alabama
Power
i—
i550
i—
i700
i1,250
i1,250
i—
Georgia
Power
i—
i—
i—
i1,750
i1,750
i1,726
i—
Mississippi
Power
i—
i150
i125
i—
i275
i255
i—
Southern
Power(a)
i—
i—
i—
i600
i600
i568
i—
Southern
Company Gas(b)
i250
i—
i—
i1,500
i1,750
i1,747
i250
SEGCO
i30
i—
i—
i—
i30
i30
i30
Southern
Company
$
i280
$
i700
$
i125
$
i6,550
$
i7,655
$
i7,574
$
i280
(a)Does
not include Southern Power Company's itwo $ii75/
million continuing letter of credit facilities for standby letters of credit, expiring in 2023 and 2025, respectively, of which $i11 million and $i19
million, respectively, was unused at March 31, 2022. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.
(b)Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $i800 million of the arrangement expiring in 2026 and all $i250
million of the arrangement expiring in 2022. Southern Company Gas' committed credit arrangement expiring in 2026 also includes $i700 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.
/
As
reflected in the table above, in March 2022, Mississippi Power amended and restated its $i125 million revolving credit arrangement, which among other things, extended the maturity date from 2023 to 2025 and allows for borrowing based on term SOFR.
Subject to applicable market conditions, Southern Company and its subsidiaries expect to renew or replace their bank credit arrangements as needed, prior to expiration. In connection therewith, Southern Company and its subsidiaries may extend the
maturity dates and/or increase or decrease the lending commitments thereunder.
These bank credit arrangements, as well as the term loan arrangements of the Registrants, Nicor Gas, and SEGCO, contain covenants that limit debt levels and contain cross-acceleration or, in the case of Southern Power, cross-default provisions to other indebtedness (including guarantee obligations) that are restricted only to the indebtedness of the individual company. Such cross-default provisions to other indebtedness would trigger an event of default if Southern Power defaulted on indebtedness or guarantee obligations over a specified threshold. Such cross-acceleration provisions to other indebtedness would trigger an event of default if the applicable borrower defaulted on indebtedness, the payment of which was then accelerated. At March 31, 2022, the Registrants, Nicor Gas, and SEGCO were in
compliance with all such covenants. None of the bank credit arrangements contain material adverse change clauses at the time of borrowings.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
A portion of the unused credit with banks is allocated to provide liquidity support to the revenue bonds of the traditional electric
operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity support at March 31, 2022 was approximately $i1.5 billion (comprised of approximately $i789
million at Alabama Power, $i672 million at Georgia Power, and $i34
million at Mississippi Power). In addition, at March 31, 2022, Georgia Power had approximately $i330 million of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months.
Earnings per Share
For
Southern Company, the only differences in computing basic and diluted earnings per share are attributable to awards outstanding under stock-based compensation plans and the equity units issued in 2019. Earnings per share dilution resulting from stock-based compensation plans and the equity units issuance is determined using the treasury stock method. See Note 8 to the financial statements under "Equity Units" in Item 8 of the Form 10-K for information on the equity units and Note 12 to the financial statements in Item 8 of the Form 10-K for information on stock-based compensation plans. iShares
used to compute diluted earnings per share were as follows:
An
immaterial number of stock-based compensation awards was not included in the diluted earnings per share calculation because the awards were anti-dilutive for the three months ended March 31, 2022 and 2021.
(G) iINCOME TAXES
See Note 10 to the financial statements in Item 8 of the Form
10-K for additional tax information.
Current and Deferred Income Taxes
Tax Credit and Net Operating Loss Carryforwards
The utilization of each Registrant's estimated tax credit and state net operating loss carryforwards and related valuation allowances could be impacted by numerous factors, including the acquisition of additional renewable projects, 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 (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information on Plant Vogtle Units 3 and 4.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Effective Tax Rate
Southern Company's effective tax rate is typically lower than the statutory rate due to employee stock plans' dividend deduction, non-taxable AFUDC equity at the traditional electric operating companies, flowback of excess deferred income taxes at the regulated utilities, and federal income tax benefits from ITCs and PTCs primarily at Southern Power.
Details of significant changes in the effective tax rate for the applicable Registrants are
provided herein.
Mississippi Power
Mississippi Power's effective tax rate was i16.4% for the three months ended March 31, 2022 compared to i8.4%
for the corresponding period in 2021. The effective tax rate increase was primarily due to a decrease in the flowback of excess deferred income taxes beginning in April 2021.
Southern Power
Southern Power's effective tax benefit rate was (i80.0)% for the three months ended March 31, 2022 compared to (i17.3)%
for the corresponding period in 2021. The effective tax rate decrease was primarily due to lower pre-tax earnings and higher wind PTCs in 2022, partially offset by changes in state apportionment methodology resulting from tax legislation enacted by the State of Alabama in February 2021.
(H) iRETIREMENT BENEFITS
The Southern
Company system has a qualified defined benefit, trusteed, pension plan covering substantially all employees, with the exception of employees at PowerSecure. The qualified pension plan is funded in accordance with requirements of the Employee Retirement Income Security Act of 1974, as amended (ERISA). iNo mandatory contributions to the qualified pension plan are anticipated for the year ending December 31, 2022. The Southern
Company system also provides certain non-qualified defined benefits for a select group of management and highly compensated employees, which are funded on a cash basis. In addition, the Southern Company system provides certain medical care and life insurance benefits for retired employees through other postretirement benefit plans. The traditional electric operating companies fund other postretirement trusts to the extent required by their respective regulatory commissions. Southern Company Gas has a separate unfunded supplemental retirement health care plan that provides medical care and life insurance benefits to employees of discontinued businesses.
During the first quarter 2022, the qualified pension plan achieved the predetermined funding threshold whereby the asset allocation was adjusted to invest a larger portion of the portfolio in fixed rate debt securities.
See Note 11
to the financial statements in Item 8 of the Form 10-K for additional information.
On each Registrant's condensed statements of income, the service cost component of net periodic benefit costs is included in other operations and maintenance expenses and all other components of net periodic benefit costs are included in other income (expense), net. iComponents of the net periodic benefit costs for the three months ended March 31, 2022 and 2021
are presented in the following tables.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
(I) iFAIR VALUE MEASUREMENTS
i
At
March 31, 2022, assets and liabilities measured at fair value on a recurring basis during the period, together with their associated level of the fair value hierarchy, were as follows:
Quoted Prices in Active Markets for Identical Assets (Level 1)
Significant Other Observable Inputs (Level 2)
Significant Unobservable Inputs (Level 3)
Net Asset Value as a Practical Expedient (NAV)
Total
(in millions)
Mississippi
Power
Assets:
Energy-related derivatives
$
i—
$
i138
$
i—
$
—
$
i138
Liabilities:
Energy-related
derivatives
$
i—
$
i2
$
i—
$
—
$
i2
Southern
Power
Assets:
Energy-related derivatives
$
i—
$
i8
$
i—
$
—
$
i8
Liabilities:
Foreign
currency derivatives
$
i—
$
i43
$
i—
$
—
$
i43
Contingent
consideration
i—
i—
i14
—
i14
Other
i—
i13
i—
—
i13
Total
$
i—
$
i56
$
i14
$
—
$
i70
Southern
Company Gas
Assets:
Energy-related derivatives(a)
$
i74
$
i20
$
i—
$
—
$
i94
Non-qualified
deferred compensation trusts:
Domestic equity
i—
i8
i—
—
i8
Foreign
equity
i—
i2
i—
—
i2
Pooled
funds – fixed income
i—
i10
i—
—
i10
Cash
equivalents
i3
i—
i—
—
i3
Total
$
i77
$
i40
$
i—
$
—
$
i117
Liabilities:
Energy-related
derivatives(a)
$
i3
$
i1
$
i—
$
—
$
i4
Interest
rate derivatives
i—
i36
i—
—
i36
Total
$
i3
i
$
i37
i
$
i—
$
—
i
$
i40
(a)Excludes
cash collateral of $i36 million.
(b)Excludes receivables related to investment income, pending investment sales, payables related to pending investment purchases, and currencies. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.
(c)Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program.
At March 31, 2022, approximately $i72 million of the fair market value of Georgia Power's nuclear decommissioning trust funds' securities were on loan to creditors under the funds' managers' securities lending program. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Southern Company, Alabama Power, and Georgia Power continue to elect the option to fair value investment securities held in the nuclear decommissioning trust funds. iThe
fair value of the funds, including reinvested interest and dividends and excluding the funds' expenses, increased (decreased) by the amounts shown in the table below for the three months ended March 31, 2022 and 2021. The changes were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively.
The energy-related derivatives primarily consist of exchange-traded and over-the-counter financial products for natural gas and physical power products, including, from time to time, basis swaps. These are standard products used within the energy industry and are valued using the market approach. The inputs used are mainly from observable market sources, such as forward natural gas prices, power prices, implied volatility, and overnight index swap interest rates. Interest rate derivatives are also standard over-the-counter products that are valued using observable market data and assumptions commonly used by market participants. The fair value of interest rate derivatives reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future interest rates. Additional inputs to the net present value calculation may include the contract terms, counterparty
credit risk, and occasionally, implied volatility of interest rate options. The fair value of cross-currency swaps reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future foreign currency exchange rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and discount rates. The interest rate derivatives and cross-currency swaps are categorized as Level 2 under Fair Value Measurements as these inputs are based on observable data and valuations of similar instruments. See Note (J) for additional information on how these derivatives are used.
For fair value measurements of the investments within the nuclear decommissioning trusts and the non-qualified deferred compensation trusts, external pricing vendors are designated for each asset class with each security specifically assigned a primary
pricing source. For investments held within commingled funds, fair value is determined at the end of each business day through the net asset value, which is established by obtaining the underlying securities' individual prices from the primary pricing source. A market price secured from the primary source vendor is then evaluated by management in its valuation of the assets within the trusts. As a general approach, fixed income market pricing vendors gather market data (including indices and market research reports) and integrate relative credit information, observed market movements, and sector news into proprietary pricing models, pricing systems, and mathematical tools. Dealer quotes and other market information, including live trading levels and pricing analysts' judgments, are also obtained when available.
The NRC requires licensees of commissioned nuclear power reactors to establish a plan for providing reasonable assurance
of funds for future decommissioning. See Note 6 to the financial statements under "Nuclear Decommissioning" in Item 8 of the Form 10-K for additional information.
Southern Power has contingent payment obligations related to certain acquisitions whereby it is primarily obligated to make generation-based payments to the seller, which commenced at the commercial operation of the respective facility and continue through 2026. The obligations are categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable inputs for the forecasted facility generation in MW-hours, as well as other inputs such as a fixed dollar amount per MW-hour, and a discount rate. The fair value of contingent consideration reflects the net present value of expected payments and any periodic change arising from forecasted generation is expected to be immaterial.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Southern Power also has payment obligations through 2040 whereby it must reimburse the transmission owners for interconnection facilities and network upgrades constructed to support connection of a Southern Power generating facility to the transmission system. The obligations are categorized as Level 2 under Fair Value Measurements as the fair value is determined using observable inputs for the contracted amounts and reimbursement period, as well as a discount rate. The fair value of the obligations reflects the net present value of expected payments.
"Other
investments" include investments traded in the open market that have maturities greater than 90 days, which are categorized as Level 2 under Fair Value Measurements and are comprised of corporate bonds, bank certificates of deposit, treasury bonds, and/or agency bonds.
At March 31, 2022, the fair value measurements of private equity investments held in Alabama Power's nuclear decommissioning trusts that are calculated at net asset value per share (or its equivalent) as a practical expedient totaled $i156
million and unfunded commitments related to the private equity investments totaled $i84 million. Private equity investments include high-quality private equity funds across several market sectors and funds that invest in real estate assets. Private equity funds do not have redemption rights. Distributions from these funds will be received as the underlying investments in the funds are liquidated.
i
At
March 31, 2022, other financial instruments for which the carrying amount did not equal fair value were as follows:
Southern Company
Alabama Power
Georgia Power
Mississippi Power
Southern Power
Southern
Company Gas(*)
(in billions)
Long-term debt, including securities due within one year:
Carrying amount
$
i51.6
$
i9.8
$
i13.2
$
i1.5
$
i3.7
$
i6.9
Fair
value
i51.9
i10.0
i13.5
i1.5
i3.8
i6.9
(*)The
long-term debt of Southern Company Gas is recorded at amortized cost, including the fair value adjustments at the effective date of the 2016 merger with Southern Company. Southern Company Gas amortizes the fair value adjustments over the remaining lives of the respective bonds, the latest being through 2043.
/
The fair values are determined using Level 2 measurements and are based on quoted market prices for the same or similar issues or on the current rates available to the Registrants.
(J) iDERIVATIVES
iThe
Registrants are exposed to market risks, including commodity price risk, interest rate risk, weather risk, and occasionally foreign currency exchange rate risk. To manage the volatility attributable to these exposures, each company nets its exposures, where possible, to take advantage of natural offsets and enters into various derivative transactions for the remaining exposures pursuant to each company's policies in areas such as counterparty exposure and risk management practices. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' wholesale gas operations used various contracts in its commercial activities that generally met the definition of derivatives. For the traditional electric operating companies, Southern Power, and Southern Company Gas' other businesses, each company's policy is that derivatives are to be used primarily for hedging purposes and mandates strict adherence to all applicable risk
management policies. Derivative positions are monitored using techniques including, but not limited to, market valuation, value at risk, stress testing, and sensitivity analysis. Derivative instruments are recognized at fair value in the balance sheets as either assets or liabilities and are presented on a net basis. See Note (I) for additional fair value information. In the statements of cash flows, any cash impacts of settled energy-related and interest rate derivatives are recorded as operating activities. Any cash impacts of settled foreign currency derivatives are classified as operating or financing activities to correspond with the classification of the hedged interest or principal, respectively. See Note 1 to the financial statements under "Financial Instruments" in Item 8 of the Form 10-K for additional information. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information regarding
the sale of Sequent.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Energy-Related Derivatives
The Subsidiary Registrants enter into energy-related derivatives to hedge exposures to electricity, natural gas, and other fuel price changes. However, due to cost-based rate
regulations and other various cost recovery mechanisms, the traditional electric operating companies and the natural gas distribution utilities have limited exposure to market volatility in energy-related commodity prices. Each of the traditional electric operating companies and certain of the natural gas distribution utilities of Southern Company Gas manage fuel-hedging programs, implemented per the guidelines of their respective state PSCs or other applicable state regulatory agencies, through the use of financial derivative contracts, which are expected to continue to mitigate price volatility. The traditional electric operating companies (with respect to wholesale generating capacity) and Southern Power have limited exposure to market volatility in energy-related commodity prices because their long-term sales contracts shift substantially all fuel cost responsibility to the purchaser. However, the traditional electric operating companies and Southern Power may be
exposed to market volatility in energy-related commodity prices to the extent any uncontracted capacity is used to sell electricity. Southern Company Gas retains exposure to price changes that can, in a volatile energy market, be material and can adversely affect its results of operations.
Southern Company Gas also enters into weather derivative contracts as economic hedges in the event of warmer-than-normal weather. Exchange-traded options are carried at fair value, with changes reflected in operating revenues. Non-exchange-traded options are accounted for using the intrinsic value method. Changes in the intrinsic value for non-exchange-traded contracts are reflected in operating revenues.
Energy-related derivative contracts are accounted for under one of three methods:
•Regulatory Hedges –
Energy-related derivative contracts designated as regulatory hedges relate primarily to the traditional electric operating companies' and the natural gas distribution utilities' fuel-hedging programs, where gains and losses are initially recorded as regulatory liabilities and assets, respectively, and then are included in fuel expense as the underlying fuel is used in operations and ultimately recovered through an approved cost recovery mechanism.
•Cash Flow Hedges – Gains and losses on energy-related derivatives designated as cash flow hedges (which are mainly used to hedge anticipated purchases and sales) are initially deferred in accumulated OCI before being recognized in the statements of income in the same period and in the same income statement line item as the earnings effect of the hedged transactions.
•Not
Designated – Gains and losses on energy-related derivative contracts that are not designated or fail to qualify as hedges are recognized in the statements of income as incurred.
Some energy-related derivative contracts require physical delivery as opposed to financial settlement, and this type of derivative is both common and prevalent within the electric and natural gas industries. When an energy-related derivative contract is settled physically, any cumulative unrealized gain or loss is reversed and the contract price is recognized in the respective line item representing the actual price of the underlying goods being delivered.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
i
At March 31, 2022, the net volume of energy-related derivative contracts for natural gas positions, together with the longest hedge date over which the
respective entity is hedging its exposure to the variability in future cash flows for forecasted transactions and the longest non-hedge date for derivatives not designated as hedges, were as follows:
Net Purchased mmBtu
Longest Hedge Date
Longest Non-Hedge Date
(in millions)
Southern
Company(*)
i279
2030
2025
Alabama Power
i65
2025
—
Georgia
Power
i75
2024
—
Mississippi Power
i71
2026
—
Southern
Power
i4
2030
—
Southern Company Gas(*)
i64
2024
2025
(*)Southern
Company Gas' derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and a short position is a contract to sell natural gas. Southern Company Gas' volume represents the net of long natural gas positions of i66.2 million mmBtu and short natural gas positions of i2.6
million mmBtu at March 31, 2022, which is also included in Southern Company's total volume.
/
In addition to the volumes discussed above, the traditional electric operating companies and Southern Power enter into physical natural gas supply contracts that provide the option to sell back excess natural gas due to operational constraints. The maximum expected volume of natural gas subject to such a feature is i18
million mmBtu for Southern Company, which includes i4 million mmBtu for Alabama Power, i6
million mmBtu for Georgia Power, i3 million mmBtu for Mississippi Power, and i5
million mmBtu for Southern Power.
For cash flow hedges of energy-related derivatives, the estimated pre-tax gains expected to be reclassified from accumulated OCI to earnings for the 12-month period ending March 31, 2023 are $i29 million for Southern Company, $i26
million for Southern Company Gas, and immaterial for all other Registrants.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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.
i
At
March 31, 2022, the following interest rate derivatives were outstanding:
For
cash flow hedge interest rate derivatives, the estimated pre-tax gains (losses) expected to be reclassified from accumulated OCI to interest expense for the 12-month period ending March 31, 2023 total $(i20) 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, Alabama Power, and
Georgia Power, 2028 for Mississippi Power, and 2046 for Southern Company Gas.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Foreign Currency Derivatives
Southern Company and certain subsidiaries, including Southern Power, may enter into foreign currency derivatives to hedge
exposure to changes in foreign currency exchange rates, such as that arising from the issuance of debt denominated in a currency other than U.S. dollars. Derivatives related to forecasted transactions are accounted for as cash flow hedges where the derivatives' fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and on the same income statement line as the earnings effect of the hedged transactions, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Derivatives related to existing fixed rate securities are accounted for as fair value hedges, where the derivatives' fair value gains or losses and hedged items' fair value gains or losses are both recorded directly to earnings on the same income statement line item, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Southern Company has elected to exclude the cross-currency basis
spread from the assessment of effectiveness in the fair value hedges of its foreign currency risk and record any difference between the change in the fair value of the excluded components and the amounts recognized in earnings as a component of OCI.
i
At March 31, 2022, the following foreign currency derivatives were outstanding:
The
estimated pre-tax losses related to Southern Power's foreign currency derivatives accounted for as cash flow hedges expected to be reclassified from accumulated OCI to earnings for the 12-month period ending March 31, 2023 are $i17 million.
Derivative Financial Statement Presentation and Amounts
The Registrants enter into derivative
contracts that may contain certain provisions that permit intra-contract netting of derivative receivables and payables for routine billing and offsets related to events of default and settlements. Southern Company and certain subsidiaries also utilize master netting agreements to mitigate exposure to counterparty credit risk. These agreements may contain provisions that permit netting across product lines and against cash collateral. The fair value amounts of derivative assets and liabilities on the balance sheets are presented net to the extent that there are netting arrangements or similar agreements with the counterparties.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
i
The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets as follows:
Derivatives designated as hedging instruments for regulatory purposes
Energy-related
derivatives:
Assets from risk management activities/Other current liabilities
$
i49
$
i1
$
i15
$
i12
Other
deferred charges and assets/Other deferred credits and liabilities
i3
i—
i—
i—
Total
derivatives designated as hedging instruments for regulatory purposes
$
i52
$
i1
$
i15
$
i12
Derivatives
designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities
$
i25
$
i2
$
i5
$
i5
Other
deferred charges and assets/Other deferred credits and liabilities
i2
i—
i—
i—
Interest
rate derivatives:
Assets from risk management activities/Liabilities from risk management activities-current
i—
i—
i6
i—
Other
deferred charges and assets/Other deferred credits and liabilities
i—
i36
i—
i6
Total
derivatives designated as hedging instruments in cash flow and fair value hedges
$
i27
$
i38
$
i11
$
i11
Derivatives
not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities
$
i14
$
i1
$
i8
$
i4
Other
deferred charges and assets/Other deferred credits and liabilities
i1
i—
i1
i—
Total
derivatives not designated as hedging instruments
$
i15
$
i1
$
i9
$
i4
Gross
amounts recognized
$
i94
$
i40
$
i35
$
i27
Gross
amounts offset(a)
(i40)
(i4)
(i8)
(i11)
Net
amounts recognized in the Balance Sheets(b)
$
i54
$
i36
$
i27
$
i16
(a)Gross
amounts offset include cash collateral held on deposit in broker margin accounts of $i36 million and $i3 million
at March 31, 2022 and December 31, 2021, respectively.
(b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives for both periods presented.
Energy-related derivatives not designated as hedging instruments were immaterial for the traditional electric operating companies at March 31, 2022. There were no such instruments for the traditional electric operating companies at December 31, 2021.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
i
At March 31, 2022 and December 31, 2021, the pre-tax effects of
unrealized derivative gains (losses) arising from energy-related derivative instruments designated as regulatory hedging instruments and deferred were as follows:
Regulatory Hedge Unrealized Gain (Loss) Recognized in the Balance Sheet
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
i
For the three months ended March 31, 2022 and 2021,
the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI were as follows:
(*)Represents
amounts excluded from the assessment of effectiveness for which the difference between changes in fair value and periodic amortization is recorded in OCI.
/
For the three months ended March 31, 2022 and 2021, the pre-tax effects of interest rate derivatives designated as cash flow hedging instruments on accumulated OCI were immaterial for the other Registrants.
Total
interest expense, net of amounts capitalized
(i462)
(i450)
Gain
(loss) on interest rate cash flow hedges(a)
(i7)
(i7)
Gain
(loss) on foreign currency cash flow hedges(a)
(i6)
(i6)
Gain
(loss) on interest rate fair value hedges(b)
(i123)
(i10)
Total
other income (expense), net
i145
i58
Gain
(loss) on foreign currency cash flow hedges(a)(c)
(i25)
(i60)
Gain
(loss) on foreign currency fair value hedges
(i24)
i—
Amount
excluded from effectiveness testing recognized in earnings
(i4)
i—
Southern
Power
Total depreciation and amortization
$
i120
$
i119
Gain
(loss) on energy-related cash flow hedges(a)
i2
i3
Total
interest expense, net of amounts capitalized
(i37)
(i38)
Gain
(loss) on foreign currency cash flow hedges(a)
(i6)
(i6)
Total
other income (expense), net
i2
i7
Gain
(loss) on foreign currency cash flow hedges(a)(c)
(i25)
(i60)
Southern
Company Gas
Total cost of natural gas
$
i1,095
$
i583
Gain
(loss) on energy-related cash flow hedges(a)
i9
i—
Total
interest expense, net of amounts capitalized
(i61)
(i60)
Gain
(loss) on interest rate cash flow hedges(a)
(i1)
i—
Gain
(loss) on interest rate fair value hedges(b)
(i36)
i—
(a)Reclassified
from accumulated OCI into earnings.
(b)For fair value hedges, changes in the fair value of the derivative contracts are generally equal to changes in the fair value of the underlying debt and have no material impact on income.
(c)The reclassification from accumulated OCI into other income (expense), net completely offsets currency gains and losses arising from changes in the U.S. currency exchange rates used to record the euro-denominated notes.
/
For the three months ended March 31, 2022 and 2021,
the pre-tax effects of cash flow and fair value hedge accounting on income for energy-related derivatives and interest rate derivatives were immaterial for the traditional electric operating companies.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
i
At
March 31, 2022 and December 31, 2021, the following amounts were recorded on the balance sheets related to cumulative basis adjustments for fair value hedges:
Carrying Amount of the Hedged Item
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item
For
the three months ended March 31, 2022 and 2021, the pre-tax effects of energy-related derivatives not designated as hedging instruments on the statements of income of Southern Company and Southern Company Gas were as follows:
Gain (Loss)
Three
Months Ended March 31,
Derivatives in Non-Designated Hedging Relationships
Statements of Income Location
2022
2021
(in millions)
Energy-related derivatives:
Natural
gas revenues(*)
$
i2
$
(i17)
Cost
of natural gas
i21
i7
Total
derivatives in non-designated hedging relationships
$
i23
$
(i10)
(*)Excludes
immaterial gains (losses) recorded in natural gas revenues associated with weather derivatives for all periods presented.
/
For the three months ended March 31, 2022 and 2021, the pre-tax effects of interest rate derivatives not designated as hedging instruments were immaterial for Southern Company and Southern Company Gas and the pre-tax effects of energy-related derivatives not designated as hedging instruments were immaterial for all other Registrants.
Contingent Features
The Registrants do not have any credit arrangements that would require material changes in payment
schedules or terminations as a result of a credit rating downgrade. There are certain derivatives that could require collateral, but not accelerated payment, in the event of various credit rating changes of certain Southern Company subsidiaries. At March 31, 2022, the Registrants had ino 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 March 31, 2022. The maximum potential collateral requirements arising from the credit-risk-related contingent features for the traditional electric operating companies and Southern Power include certain agreements that could require collateral in the event that one or more Southern Company power pool participants has a credit rating change to below investment grade. Following the sale of Gulf Power to NextEra Energy, Inc., Gulf Power has continued participating in the Southern Company power pool; however, the parties currently expect this participation to end during the third quarter 2022.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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 March 31, 2022, cash collateral posted in these accounts was immaterial. Southern Company Gas maintains accounts with brokers or the clearing houses of certain exchanges to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, Southern Company Gas may be required to deposit cash into these accounts. At March 31, 2022, cash collateral held on deposit in broker margin accounts was $i36
million.
The Registrants are exposed to losses related to financial instruments in the event of counterparties' nonperformance. The Registrants only enter into agreements and material transactions with counterparties that have investment grade credit ratings by Moody's and S&P or with counterparties who have posted collateral to cover potential credit exposure. The Registrants have also established risk management policies and controls to determine and monitor the creditworthiness of counterparties in order to mitigate their exposure to counterparty credit risk.
Southern Company Gas uses established credit policies to determine and monitor the creditworthiness of counterparties, including requirements to post collateral or other credit security, as well as the quality of pledged collateral. Collateral or credit security is most often in the form of cash or letters of credit from
an investment-grade financial institution, but may also include cash or U.S. government securities held by a trustee. Prior to entering a physical transaction, Southern Company Gas assigns its counterparties an internal credit rating and credit limit based on the counterparties' Moody's, S&P, and Fitch ratings, commercially available credit reports, and audited financial statements. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary.
Southern Company Gas utilizes netting agreements whenever possible to mitigate exposure to counterparty credit risk. Netting agreements enable Southern Company Gas to net certain assets and liabilities by counterparty across product lines and against cash collateral, provided the netting and cash collateral agreements include such provisions. While the amounts due from, or owed to, counterparties are settled net, they are recorded on a gross
basis on the balance sheet as energy marketing receivables and energy marketing payables.
The Registrants do not anticipate a material adverse effect on their respective financial statements as a result of counterparty nonperformance.
NOTES TO THE CONDENSED FINANCIAL
STATEMENTS (Continued)
(UNAUDITED)
(K) iACQUISITIONS AND DISPOSITIONS
See Note 15 to the financial statements in Item 8 of the Form 10-K for additional information.
Southern Power
Construction Projects
During
the three months ended March 31, 2022, Southern Power completed construction of and placed in service the remaining i40 MWs of the Tranquillity battery energy storage facility and the remaining i15
MWs of the Garland battery energy storage facility.
i
Project Facility
Resource
Approximate
Nameplate Capacity (MW)
Location
COD
PPA Contract Period
Projects Completed During the Three Months Ended March 31, 2022
Garland Solar Storage(a)
Battery energy storage system
i88
Kern
County, CA
September 2021
through February 2022(b)
i20 years
Tranquillity Solar Storage(a)
Battery energy storage system
i72
Fresno
County, CA
November 2021
through March 2022(c)
i20 years
(a)Southern Power consolidates each project's operating results in its financial statements and the tax equity partner and two other partners each own a noncontrolling interest.
(b)The facility has a total capacity of i88
MWs, of which i73 MWs were placed in service in 2021 and i15 MWs were placed in service in February 2022.
(c)The facility has a total capacity of i72
MWs, of which i32 MWs were placed in service in 2021 and i40 MWs were placed in service in March 2022.
/
(L)
iSEGMENT AND RELATED INFORMATION
Southern Company
The primary businesses of the Southern Company system are electricity sales by the traditional electric operating companies and Southern Power and the distribution of natural gas by Southern Company Gas. The traditional electric operating companies are vertically integrated utilities providing electric service in ithree
Southeastern states. Southern Power develops, constructs, acquires, owns, and manages power generation assets, including renewable energy and battery energy storage projects, and sells electricity at market-based rates in the wholesale market. Southern Company Gas distributes natural gas through its natural gas distribution utilities and is involved in several other complementary businesses including gas pipeline investments and gas marketing services. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' other businesses also included wholesale gas services.
Southern Company's reportable business segments are the sale of electricity by the traditional electric operating companies, the sale of electricity in the competitive wholesale market by Southern Power, and the sale of natural gas and other complementary products and services by Southern Company Gas. Revenues
from sales by Southern Power to the traditional electric operating companies were $i105 million and $i81
million for the three months ended March 31, 2022 and 2021, respectively. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies were immaterial for both periods presented. Revenues from sales of natural gas from Southern Company Gas to Southern Power were $i12 million for the three months ended March 31, 2021,
which represented sales from Sequent prior to its sale. The "All Other" column includes the Southern Company parent entity, which does not allocate operating expenses to business segments. Also, this category includes segments below the quantitative threshold for separate disclosure. These segments include providing distributed energy and resilience solutions and deploying microgrids for commercial, industrial, governmental, and utility customers, as well as investments in telecommunications and, for the three months ended March 31, 2021, leveraged lease projects. All other inter-segment revenues are not material.
(b)For the traditional electric operating companies, includes a pre-tax charge of $i48 million ($i36 million
after tax) at Georgia Power for estimated losses associated with the construction of Plant Vogtle Units 3 and 4. See Note (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.
(c)For Southern Power, includes gains on wind turbine equipment contributed to various equity method investments totaling approximately $i37 million pre-tax ($i28 million
after tax). See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.
(*)Prior
to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. See "Southern Company Gas" herein and Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Southern Company Gas
Southern Company Gas manages its business through ithree reportable segments – gas distribution operations, gas pipeline investments, and gas marketing services. Prior to the sale of Sequent on July 1, 2021, Southern
Company Gas' reportable segments also included wholesale gas services. The non-reportable segments are combined and presented as all other. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information on the sale of Sequent.
Gas distribution operations is the largest component of Southern Company Gas' business and includes natural gas local distribution utilities that construct, manage, and maintain intrastate natural gas pipelines and gas distribution facilities in ifour
states.
Gas pipeline investments consists of joint ventures in natural gas pipeline investments including a i50% interest in SNG and a i50% 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 i20% ownership interest in the PennEast Pipeline project, which was cancelled in September 2021. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.
Through July 1, 2021, wholesale gas services provided
natural gas asset management and/or related logistics services for each of Southern Company Gas' utilities except Nicor Gas as well as for non-affiliated companies. Additionally, wholesale gas services engaged in natural gas storage and gas pipeline arbitrage and related activities.
Gas marketing services provides natural gas marketing to end-use customers primarily in Georgia and Illinois through SouthStar.
The all other column includes segments and subsidiaries that fall below the quantitative threshold for separate disclosure, including storage and fuels operations.
Business segment financial data for the three months ended March 31, 2022 and 2021 was as follows:
(*)As
a result of the sale of Sequent, wholesale gas services is no longer a reportable segment for the three months ended March 31, 2022. Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and intercompany revenues is shown in the following table.
The following Management's Discussion and Analysis of Financial Condition and Results of Operations is a combined presentation; however, information contained herein relating to any individual Registrant is filed by such Registrant on its own behalf and each Registrant makes no representation as to information related to the other Registrants.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS
OVERVIEW
Southern Company is a holding company that owns all of the common stock of three traditional electric operating companies (Alabama Power, Georgia Power, and Mississippi Power), Southern Power, and Southern Company Gas and owns other direct and indirect subsidiaries. The primary businesses of the Southern Company system are electricity sales by the traditional electric operating companies and Southern Power and the distribution of natural gas by Southern Company Gas. Southern
Company's reportable segments are the sale of electricity by the traditional electric operating companies, the sale of electricity in the competitive wholesale market by Southern Power, and the sale of natural gas and other complementary products and services by Southern Company Gas. Southern Company Gas' reportable segments are gas distribution operations, gas pipeline investments, and gas marketing services. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' reportable segments also included wholesale gas services. See Note (L) to the Condensed Financial Statements herein for additional information on segment reporting. For additional information on the Registrants' primary business activities and the sale of Sequent, see BUSINESS – "The Southern Company System" in Item 1 of the Form 10-K and Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K, respectively.
The
Registrants continue to focus on several key performance indicators. For the traditional electric operating companies and Southern Company Gas, these indicators include, but are not limited to, customer satisfaction, plant availability, electric and natural gas system reliability, and execution of major construction projects. For Southern Power, these indicators include, but are not limited to, the equivalent forced outage rate and contract availability to evaluate operating results and help ensure its ability to meet its contractual commitments to customers. In addition, Southern Company and the Subsidiary Registrants focus on earnings per share and net income, respectively, as a key performance indicator.
Recent Developments
Georgia
Power
Plant Vogtle Units 3 and 4 Construction and Start-Up Status
Construction continues on Plant Vogtle Units 3 and 4 (with electric generating capacity of approximately 1,100 MWs each), in which Georgia Power currently holds a 45.7% ownership interest. Georgia Power's share of the total project capital cost forecast to complete Plant Vogtle Units 3 and 4, including contingency, through the end of the first quarter 2023 and the fourth quarter 2023, respectively, is $10.4 billion.
Fuel load for Unit 3 is projected during the third quarter or the fourth quarter 2022 with an in-service date projected during the fourth quarter 2022 or the first quarter 2023. Unit 3's projected schedule primarily depends on improvements in overall construction productivity and production levels, the volume and completion of construction remediation work, completion
of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, the pace of system and area turnovers, and the progression of startup and other testing. An in-service date during the third quarter or the fourth quarter 2023 for Unit 4 is projected. Unit 4's projected schedule primarily depends on overall construction productivity and production levels improving as well as appropriate levels of craft laborers, particularly electricians and pipefitters, being added and maintained. Any further delays could result in later in-service dates.
Georgia Power and the other Vogtle Owners do not agree on the starting dollar amount for the determination of cost increases subject to the cost-sharing and tender provisions of the Global Amendments (as defined in Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction – Joint Owner Contracts"
herein). The other Vogtle Owners have notified Georgia Power that they believe the current project capital cost forecast exceeds the cost-sharing thresholds and triggers the tender provisions under the Global Amendments. In October 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.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
During the first quarter 2022, established construction contingency totaling $43 million was assigned to the base capital cost forecast for costs primarily associated with construction productivity, the pace of system turnovers, and support resources for Units 3 and 4.
The ultimate impact of these matters on the construction schedule and project capital cost forecast for Plant Vogtle Units 3 and 4 cannot be determined at this time. See Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information.
Rate Plan
Georgia
Power is required to file its next general base rate case by June 24, 2022. See Note 2 to the financial statements under "Georgia Power – Rate Plans" in Item 8 of the Form 10-K for additional information.
Mississippi Power
On March 15, 2022, Mississippi Power submitted its annual retail PEP filing for 2022 to the Mississippi PSC, which requested a 1.9%, or approximately $18 million, annual increase in revenues. In accordance with the PEP rate schedule, the rate increase became effective with the first billing cycle of April 2022, subject to refund. The related proceedings are expected to conclude in summer 2022; however, the ultimate outcome of this matter
cannot be determined at this time.
Southern Power
During the three months ended March 31, 2022, Southern Power completed construction of and placed in service the remaining 40 MWs of the Tranquillity battery energy storage facility and the remaining 15 MWs of the Garland battery energy storage facility. See Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information.
At March 31, 2022, Southern Power's average investment coverage ratio for its generating assets, including those owned with various partners, based on the ratio of investment under contract to total investment
using the respective facilities' net book value (or expected in-service value for facilities under construction) as the investment amount was 95% through 2026 and 92% through 2031, with an average remaining contract duration of approximately 13 years.
Southern Company Gas
On April 7, 2022, Virginia Natural Gas notified the Virginia State Corporation Commission of its intent to file a base rate case in the third quarter 2022. The ultimate outcome of this matter cannot be determined at this time.
RESULTS OF OPERATIONS
Southern
Company
Net Income
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(103)
(9.1)
Consolidated
net income attributable to Southern Company was $1.0 billion ($0.97 per share) for first quarter 2022 compared to $1.1 billion ($1.07 per share) for the corresponding period in 2021. The decrease was primarily due to the first quarter 2021 net income of $126 million at Sequent, which was sold on July 1, 2021, and higher non-fuel operations and maintenance costs, partially offset by an increase in natural gas revenues from base rate increases and continued infrastructure replacement, an increase in retail electric revenues primarily from base tariff increases in accordance with Georgia Power's 2019 ARP, and a $36 million after-tax charge in the first quarter 2021 related to the construction of Plant Vogtle Units 3 and 4.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Retail Electric Revenues
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$271
8.1
In
the first quarter 2022, retail electric revenues were $3.6 billion compared to $3.3 billion for the corresponding period in 2021.
Details of the changes in retail electric revenues were as follows:
First Quarter 2022
(in millions)
(% change)
Retail
electric – prior year
$
3,342
Estimated change resulting from –
Rates and pricing
56
1.7
%
Sales
growth
20
0.6
Weather
16
0.5
Fuel and other cost recovery
179
5.3
Retail
electric – current year
$
3,613
8.1
%
Revenues associated with changes in rates and pricing increased in the first quarter 2022 when compared to the corresponding period in 2021. The increase was primarily due to base tariff increases in accordance with Georgia Power's 2019 ARP. See Note 2 to the financial statements under "Georgia Power – Rate Plans" in Item 8 of the Form 10-K for additional information.
Revenues attributable to changes in sales increased in the first quarter 2022 when compared to the corresponding
period in 2021. Weather-adjusted residential KWH sales decreased 1.1% and weather-adjusted commercial KWH sales increased 1.9% in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to impacts on customer usage from increased activity outside the home following the expiration of COVID-19 restrictions. Increased customer growth partially offset the decrease in residential KWH sales and contributed to the increase in commercial KWH sales. Industrial KWH sales increased 1.7% in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to strength in the pipeline segment.
Fuel and other cost recovery revenues increased $179 million in the first quarter 2022 compared to the corresponding period in 2021 primarily due to higher fuel and purchased power costs. Electric rates for the traditional electric operating companies include provisions to adjust billings for fluctuations
in fuel costs, including the energy component of purchased power costs. Under these provisions, fuel revenues generally equal fuel expenses, including the energy component of PPA costs, and do not affect net income. The traditional electric operating companies each have one or more regulatory mechanisms to recover other costs such as environmental and other compliance costs, storm damage, new plants, and PPA capacity costs.
Wholesale Electric Revenues
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$119
21.8
In the first quarter 2022, wholesale electric revenues were $664 million compared to $545 million for the corresponding period in 2021. The increase was primarily due to a $117 million increase in energy revenues in the first quarter 2022 as a result of higher natural gas prices when compared to the corresponding period
in 2021 and an increase in the volume of KWHs sold at Southern Power primarily associated with natural gas PPAs.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Wholesale electric revenues consist of revenues from PPAs and short-term opportunity sales. Wholesale electric revenues from PPAs
(other than solar and wind PPAs) have both capacity and energy components. Capacity revenues generally represent the greatest contribution to net income and are designed to provide recovery of fixed costs plus a return on investment. Energy revenues will vary depending on fuel prices, the market prices of wholesale energy compared to the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. Energy sales from solar and wind PPAs do not have a capacity charge and customers either purchase the energy output of a dedicated renewable facility through an energy charge or through a fixed price related to the energy. As a result, the ability to recover fixed and variable
operations and maintenance expenses is dependent upon the level of energy generated from these facilities, which can be impacted by weather conditions, equipment performance, transmission constraints, and other factors. Wholesale electric revenues at Mississippi Power include FERC-regulated municipal and rural association sales under cost-based tariffs as well as market-based sales. Short-term opportunity sales are made at market-based rates that generally provide a margin above the Southern Company system's variable cost to produce the energy.
Natural Gas Revenues
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$364
21.5
In the first quarter 2022, natural gas revenues were $2.1 billion compared to $1.7 billion for the corresponding period in 2021.
Details of the changes in natural gas revenues were as follows:
First
Quarter 2022
(in millions)
(% change)
Natural gas revenues – prior year
$
1,694
Estimated change resulting from –
Infrastructure
replacement programs and base rate changes
86
5.1
%
Gas costs and other cost recovery
544
32.1
Gas marketing services
18
1.1
Wholesale
gas services
(297)
(17.5)
Other
13
0.7
Natural gas revenues – current year
$
2,058
21.5
%
Revenues
from infrastructure replacement programs and base rate changes at the natural gas distribution utilities increased in the first quarter 2022 compared to the corresponding period in 2021 primarily due to rate increases at Atlanta Gas Light and Chattanooga Gas and continued investment in infrastructure replacement. See Note 2 to the financial statements under "Southern Company Gas – Rate Proceedings" in Item 8 of the Form 10-K for additional information.
Revenues associated with gas costs and other cost recovery increased in the first quarter 2022 compared to the corresponding period in 2021 primarily due to higher volumes of natural gas sold and higher natural gas cost recovery. Natural gas distribution rates include provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas and do not affect
net income from the natural gas distribution utilities.
Revenues from gas marketing services increased in the first quarter 2022 compared to the corresponding period in 2021 primarily due to higher commodity prices and higher sales to commercial customers.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
The
change in revenues related to Southern Company Gas' wholesale gas services was due to the sale of Sequent on July 1, 2021. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.
Other Revenues
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(23)
(14.5)
In
the first quarter 2022, other revenues were $136 million compared to $159 million for the corresponding period in 2021. The decrease was primarily due to a $14 million decrease at PowerSecure primarily related to distributed infrastructure and energy efficiency projects and a $6 million decrease in unregulated sales associated with power delivery construction and maintenance projects at Georgia Power.
Fuel and Purchased Power Expenses
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
Fuel
$
263
31.0
Purchased power
25
12.1
Total
fuel and purchased power expenses
$
288
In the first quarter 2022, total fuel and purchased power expenses were $1.3 billion compared to $1.1 billion for the corresponding period in 2021. The increase was primarily the result of a $247 million increase in the average cost of fuel and purchased power and a $41 million increase in the volume of KWHs generated and purchased.
Fuel and purchased power energy transactions at the traditional electric operating companies are generally offset by fuel revenues and do not have a significant impact on net income. See Note 2 to the financial statements
in Item 8 of the Form 10-K for additional information. Fuel expenses incurred under Southern Power's PPAs are generally the responsibility of the counterparties and do not significantly impact net income.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Details of the Southern Company system's
generation and purchased power were as follows:
First Quarter 2022
First Quarter 2021
Total generation (in billions of KWHs)(a)
46
43
Total purchased power (in
billions of KWHs)
4
4
Sources of generation (percent)(a) —
Gas
46
46
Coal
23
24
Nuclear
17
17
Hydro
6
5
Wind,
Solar, and Other
8
8
Cost of fuel, generated (in cents per net KWH)—
Gas(a)
3.53
2.55
Coal
3.11
2.82
Nuclear
0.72
0.75
Average
cost of fuel, generated (in cents per net KWH)(a)
2.86
2.26
Average cost of purchased power (in cents per net KWH)(b)
5.58
5.10
(a)Excludes Central Alabama Generating Station KWHs and associated cost of fuel as its fuel is provided by the purchaser under a power sales agreement. See Note 15 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional
information.
(b)Average cost of purchased power includes fuel purchased by the Southern Company system for tolling agreements where power is generated by the provider.
Fuel
In the first quarter 2022, fuel expense was $1.1 billion compared to $0.8 billion for the corresponding period in 2021. The increase was primarily due to a 38.4% increase in the average cost of natural gas per KWH generated, a 10.3% increase in the average cost of coal per KWH generated, and a 4.6% increase in the volume of KWHs generated by natural gas, partially offset by a 41.2% increase in the volume of KWHs generated by hydro.
Purchased Power
In the first quarter 2022, purchased power expense was $232 million compared to $207 million for the corresponding
period in 2021. The increase was primarily due to a 9.4% increase in the average cost per KWH purchased primarily due to higher natural gas prices and a 4.6% increase in the volume of KWHs purchased.
Energy purchases will vary depending on demand for energy within the Southern Company system's electric service territory, the market prices of wholesale energy as compared to the cost of the Southern Company system's generation, and the availability of the Southern Company system's generation.
Cost of Natural Gas
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$512
87.8
Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, natural gas distribution rates include provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas and do not affect
net income from
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
the natural gas distribution utilities. Cost of natural gas at the natural gas distribution utilities represented 90% of total cost of natural gas for the first quarter 2022.
In the
first quarter 2022, cost of natural gas was $1.1 billion compared to $0.6 billion for the corresponding period in 2021. The increase reflects higher gas cost recovery as a result of an 83.9% increase in natural gas prices in the first quarter 2022 compared to the corresponding period in 2021.
Cost of Other Sales
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(13)
(15.9)
In
the first quarter 2022, cost of other sales was $69 million compared to $82 million for the corresponding period in 2021. The decrease was primarily due to decreases of $9 million at Georgia Power primarily associated with unregulated power delivery construction and maintenance projects and $4 million related to distributed infrastructure and energy efficiency projects at PowerSecure.
Other Operations and Maintenance Expenses
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$144
10.5
In
the first quarter 2022, other operations and maintenance expenses were $1.5 billion compared to $1.4 billion for the corresponding period in 2021. Excluding $48 million of expenses related to Sequent in 2021, other operations and maintenance expenses increased $192 million. The increase was primarily due to increases of $66 million in transmission and distribution expenses primarily related to line maintenance, $58 million in generation expenses primarily related to scheduled outage and maintenance, and $16 million in expenses at Southern Company Gas passed through directly to customers, primarily related to bad debt.
Depreciation and Amortization
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$21
2.4
In the first quarter 2022, depreciation and amortization was $892 million compared to $871 million for the corresponding period in 2021. The increase was primarily due to additional plant in service.
Taxes Other Than Income Taxes
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$27
7.8
In the first quarter 2022, taxes other than income taxes were $372 million compared to $345 million for the corresponding period in 2021. The increase primarily reflects an increase in revenue tax expenses as a result of higher natural gas revenues at Nicor Gas and an increase
in municipal franchise fees related to higher retail revenues at Georgia Power.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Estimated Loss on Plant Vogtle Units 3 and 4
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(48)
N/M
N/M - Not meaningful
In the first quarter 2021, a $48 million estimated probable loss on Plant Vogtle Units 3 and 4 was recorded at Georgia Power. The loss reflects revisions to the total project capital cost forecast to complete construction and start-up of Plant Vogtle Units
3 and 4. See Note (B) to the Condensed Financial Statements herein and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.
Gain on Dispositions, Net
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(21)
(47.7)
In
the first quarter 2022, gain on dispositions, net was $23 million compared to $44 million for the corresponding period in 2021. The first quarter 2022 amount includes $17 million in gains from sales of integrated transmission system assets at Georgia Power. The first quarter 2021 amount includes $39 million in gains at Southern Power primarily from contributions of wind turbine equipment to various equity method investments. See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.
Interest Expense, Net of Amounts Capitalized
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$12
2.7
In the first quarter 2022, interest expense, net of amounts capitalized was $462 million compared to $450 million for the corresponding period in 2021. The increase was primarily due to higher average outstanding borrowings, partially offset by lower interest rates on newly issued debt relative to the debt that was retired
since the first quarter 2021.
Other Income (Expense), Net
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$87
150.0
In
the first quarter 2022, other income (expense), net was $145 million compared to $58 million for the corresponding period in 2021. The increase was primarily due to $75 million in charitable contributions at Southern Company Gas in the first quarter 2021 and a $13 million increase in non-service cost-related retirement benefits income. See Note (H) to the Condensed Financial Statements herein for additional information.
MANAGEMENT'S
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Income Taxes
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(17)
(8.9)
In
the first quarter 2022, income taxes were $173 million compared to $190 million for the corresponding period in 2021. The decrease was primarily due to a decrease of $40 million at Southern Company Gas' wholesale gas services business as a result of the sale of Sequent on July 1, 2021, partially offset by $16 million of tax benefits in the first quarter 2021 resulting from new legislation that changed Southern Power's state apportionment methodology. See Note (G) to the Condensed Financial Statements herein for additional information.
Net Loss Attributable to Noncontrolling Interests
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$13
40.6
Substantially all noncontrolling interests relate to renewable projects at Southern Power. In the first quarter 2022, net loss attributable to noncontrolling interests was $45 million compared to $32 million for the corresponding period in 2021. The increased loss was primarily due to loss allocations to Southern Power's
partners in the Garland and Tranquillity battery energy storage facilities and higher HLBV loss allocations to Southern Power's wind tax equity partners, including new partnerships entered into during 2021. The increased loss allocations were partially offset by higher income allocations to Southern Power's solar equity partners.
Alabama Power
Net Income
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(12)
(3.3)
Alabama Power's net income after dividends on preferred stock in the first quarter 2022 was $347 million compared to $359 million for the corresponding period in 2021. The decrease was primarily due to an increase in non-fuel operations and maintenance expenses, partially
offset by an increase in retail revenues resulting from sales growth in the first quarter 2022 compared to the corresponding period in 2021.
Retail Revenues
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$27
2.0
In
the first quarter 2022, retail revenues were $1.38 billion compared to $1.35 billion for the corresponding period in 2021.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Details of the changes in retail revenues were as follows:
First
Quarter 2022
(in millions)
(% change)
Retail – prior year
$
1,352
Estimated change resulting from –
Rates
and pricing
—
—
%
Sales growth
14
1.0
Weather
1
0.1
Fuel
and other cost recovery
12
0.9
Retail – current year
$
1,379
2.0
%
Revenues attributable to changes in sales increased in the first quarter 2022 when compared to the corresponding
period in 2021. Weather-adjusted residential and commercial KWH sales increased 0.6% and 1.0%, respectively, in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to customer growth. Industrial KWH sales increased 0.1% in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to a recovering industrial class that continues to experience disruptions in supply chain and business operations.
Fuel and other cost recovery revenues increased in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to increases in the volume of KWHs generated and the average cost of fuel.
Electric rates include provisions to recognize the recovery of fuel costs, purchased power costs, PPAs certificated by the Alabama
PSC, and costs associated with the NDR. Under these provisions, fuel and other cost recovery revenues generally equal fuel and other cost recovery expenses and do not affect net income. See Note 2 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information.
Wholesale Revenues – Non-Affiliates
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$22
23.9
In
the first quarter 2022, wholesale revenues from sales to non-affiliates were $114 million compared to $92 million for the corresponding period in 2021. The increase was primarily due to a 16.2% increase in KWH sales as a result of cooler weather in the first quarter 2022 compared to the corresponding period in 2021, as well as a 6.0% increase in the price of energy due to higher natural gas prices.
Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Alabama Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not affect net income. Short-term opportunity
energy sales are also included in wholesale energy sales to non-affiliates. These opportunity sales are made at market-based rates that generally provide a margin above Alabama Power's variable cost to produce the energy.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Wholesale Revenues –
Affiliates
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$33
103.1
In
the first quarter 2022, wholesale revenues from sales to affiliates were $65 million compared to $32 million for the corresponding period in 2021. The increase was primarily due to a 47.1% increase in the price of energy due to higher natural gas prices and a 40.3% increase in KWH sales as a result of increased generation demand as a result of cooler weather in the first quarter 2022 compared to the corresponding period in 2021.
Wholesale revenues from sales to affiliated companies will vary depending on demand and the availability and cost of generating resources at each company. These affiliate sales are made in accordance with the IIC, as approved by the FERC. These transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost and energy purchases are generally offset by energy revenues through Alabama Power's energy cost recovery clause.
Fuel
and Purchased Power Expenses
First Quarter 2022 vs.
First Quarter 2021
(change in millions)
(% change)
Fuel
$
42
14.4
Purchased
power – non-affiliates
17
34.0
Purchased power – affiliates
(4)
(13.3)
Total fuel and purchased power expenses
$
55
In
the first quarter 2022, total fuel and purchased power expenses were $426 million compared to $371 million for the corresponding period in 2021. The increase was primarily due to a $39 million increase in the average cost of fuel and purchased power and a $16 million increase related to the volume of KWHs generated and purchased.
Fuel and purchased power energy transactions do not have a significant impact on earnings, since energy expenses are generally offset by energy revenues through Alabama Power's energy cost recovery clause. See Note 2 to the financial statements under "Alabama Power – Rate ECR" in Item 8 of the Form 10-K for additional information.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Details of Alabama Power's generation and purchased power were as follows:
First
Quarter 2022
First Quarter 2021
Total generation (in billions of KWHs)(a)
15
15
Total purchased power (in billions of KWHs)
2
1
Sources
of generation (percent)(a) —
Coal
42
46
Nuclear
25
25
Gas
19
19
Hydro
14
10
Cost
of fuel, generated (in cents per net KWH) —
Coal
2.90
2.75
Nuclear
0.67
0.72
Gas(a)
3.45
2.51
Average
cost of fuel, generated (in cents per net KWH)(a)
2.36
2.14
Average cost of purchased power (in cents per net KWH)(b)
6.82
6.52
(a)Excludes Central Alabama Generating Station KWHs and associated cost of fuel as its
fuel is provided by the purchaser under a power sales agreement. See Note 15 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information.
(b)Average cost of purchased power includes fuel, energy, and transmission purchased by Alabama Power for tolling agreements where power is generated by the provider.
Fuel
In the first quarter 2022, fuel expense was $333 million compared to $291 million for the corresponding period in 2021. The increase was primarily due to a 37.5% increase in the average cost of natural gas per KWH generated, which excludes tolling agreements, and a 6.3% increase in the volume of KWHs generated by natural gas, partially offset by a 49.0% increase in the volume of KWHs generated by hydro.
Purchased
Power – Non-Affiliates
In the first quarter 2022, purchased power expense from non-affiliates was $67 million compared to $50 million for the corresponding period in 2021. The increase was primarily due to a 29.9% increase in the volume of KWHs purchased as a result of cooler weather in 2022 compared to the corresponding period in 2021, as well as a 9.8% increase in the average cost per KWH purchased due to higher natural gas prices.
Energy purchases from non-affiliates will vary depending on the market prices of wholesale energy as compared to the cost of the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation.
Purchased Power – Affiliates
For first quarter 2022,
purchased power expense from affiliates was $26 million compared to $30 million for the corresponding period in 2021. The decrease was primarily due to a 17.7% decrease in the volume of KWHs purchased as a result of increased generation compared to the corresponding period in 2021, partially offset by a 5.6% increase in the average cost per KWH purchased due to higher natural gas prices.
Energy purchases from affiliates will vary depending on demand for energy and the availability and cost of generating resources at each company within the Southern Company system. These purchases are made in accordance with the IIC or other contractual agreements, as approved by the FERC.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Other Operations and Maintenance Expenses
First Quarter 2022 vs. First Quarter
2021
(change in millions)
(% change)
$48
13.3
In the first quarter 2022, other operations and maintenance expenses were $409 million compared to $361 million for the corresponding period in 2021. The increase was primarily due to increases of $26 million in generation expenses associated with scheduled outages and maintenance and Rate CNP Compliance-related expenses and $12
million in transmission and distribution expenses primarily associated with line maintenance. See Note 2 to the financial statements under "Alabama Power – Rate CNP Compliance" in Item 8 of the Form 10-K for additional information.
Georgia Power
Net Income
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$34
9.7
Georgia
Power's net income in the first quarter 2022 was $385 million compared to $351 million for the corresponding period in 2021. The increase was primarily due to higher retail revenues primarily from base tariff increases in accordance with the 2019 ARP and a $36 million after-tax charge in the first quarter 2021 related to the construction of Plant Vogtle Units 3 and 4, partially offset by higher non-fuel operations and maintenance costs. See Note (B) to the Condensed Financial Statements herein and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information regarding Plant Vogtle Units 3 and 4.
Retail Revenues
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$230
12.9
In the first quarter 2022, retail revenues were $2.02 billion compared to $1.79 billion for the corresponding period in 2021.
Details of the changes in retail revenues were as follows:
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Revenues associated with changes in rates and pricing increased in the first quarter 2022 when compared to the corresponding period in 2021. The increase was primarily due to base tariff increases in accordance with the 2019 ARP. See Note 2 to the financial statements under "Georgia Power – Rate Plans" in Item 8 of the Form 10-K for additional information.
Revenues attributable to changes in sales increased in the first quarter 2022 when compared to the corresponding
period in 2021. Weather-adjusted residential KWH sales decreased 2.3% and weather-adjusted commercial KWH sales increased 2.2% in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to the impacts on customer usage from increased activity outside the home following the expiration of COVID-19 restrictions. Increased customer growth partially offset the decrease in residential KWH sales and contributed to the increase in commercial KWH sales. Weather-adjusted industrial KWH sales increased 3.6% in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to strength in the pipeline segment.
Fuel revenues and costs are allocated between retail and wholesale jurisdictions. Retail fuel cost recovery revenues increased in the first quarter 2022 when compared to the corresponding period in 2021 due to higher fuel and purchased power costs. Electric rates include provisions
to adjust billings for fluctuations in fuel costs, including the energy component of purchased power costs. Under these fuel cost recovery provisions, fuel revenues generally equal fuel expenses and do not affect net income. See Note 2 to the financial statements under "Georgia Power – Fuel Cost Recovery" in Item 8 of the Form 10-K for additional information.
Wholesale Revenues
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$23
53.5
In
the first quarter 2022, wholesale revenues were $66 million compared to $43 million for the corresponding period in 2021. The increase was primarily due to increases of $18 million related to the average cost of fuel primarily due to higher natural gas and coal prices and $7 million in KWH sales associated with higher market demand as a result of cooler weather in the first quarter 2022 compared to the corresponding period in 2021, partially offset by a decrease of $4 million in capacity revenues from shared Southern Company power pool sales in accordance with the IIC.
Wholesale revenues from sales to non-affiliates consist of PPAs and short-term opportunity sales. Wholesale revenues from PPAs have both capacity and energy components. Wholesale capacity revenues from PPAs are recognized in amounts billable under the contract terms and provide for recovery of fixed costs and a return
on investment. Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Georgia Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. Short-term opportunity sales are made at market-based rates that generally provide a margin above Georgia Power's variable cost of energy.
Wholesale revenues from sales to affiliated companies will vary depending on demand and the availability and cost of generating resources at each company. These affiliate sales are made in accordance with the IIC, as approved by the FERC. These
transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Other Revenues
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(15)
(10.7)
In the first quarter 2022, other revenues were $125 million compared to $140 million for the corresponding period in 2021. The decrease was primarily due to decreases of $8 million resulting from the termination of a transmission service contract and $6 million in unregulated sales associated with power delivery construction
and maintenance projects.
Fuel and Purchased Power Expenses
First Quarter 2022 vs.
First Quarter 2021
(change in millions)
(% change)
Fuel
$
106
33.9
Purchased
power – non-affiliates
6
4.2
Purchased power – affiliates
70
51.5
Total fuel and purchased power expenses
$
182
In
the first quarter 2022, total fuel and purchased power expenses were $775 million compared to $593 million for the corresponding period in 2021. The increase was due to an increase of $133 million related to the average cost of fuel and purchased power and an increase of $49 million related to the volume of KWHs generated and purchased.
Fuel and purchased power energy transactions do not have a significant impact on earnings since these fuel expenses are generally offset by fuel revenues through Georgia Power's fuel cost recovery mechanism. See Note 2 to the financial statements under "Georgia Power – Fuel Cost Recovery" in Item 8 of the Form 10-K for additional information.
Details of Georgia Power's generation and purchased power were as follows:
First
Quarter 2022
First Quarter 2021
Total generation (in billions of KWHs)
15
14
Total purchased power (in billions of KWHs)
8
7
Sources of
generation (percent) —
Gas
46
47
Coal
25
22
Nuclear
24
27
Hydro
and other
5
4
Cost of fuel, generated (in cents per net KWH)—
Gas
3.58
2.58
Coal
3.41
2.91
Nuclear
0.77
0.78
Average
cost of fuel, generated (in cents per net KWH)
2.83
2.15
Average cost of purchased power (in cents per net KWH)(*)
4.81
4.22
(*)Average cost of purchased power includes fuel purchased by Georgia Power for tolling agreements where power is
generated by the provider.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Fuel
In the first quarter 2022, fuel expense was $419 million compared to $313 million for the corresponding period in 2021. The increase was primarily due to increases of
38.8% and 17.2% in the average cost per KWH generated by natural gas and coal, respectively, and a 19.5% increase in the volume of KWHs generated by coal.
Purchased Power – Affiliates
In the first quarter 2022, purchased power expense from affiliates was $206 million compared to $136 million for the corresponding period in 2021. The increase was primarily due to an increase of 25.7% in the average cost per KWH purchased primarily due to higher natural gas and coal prices and an increase of 18.3% in the volume of KWHs purchased due to lower cost Southern Company system resources as compared to available Georgia Power-owned generation.
Energy purchases from affiliates will vary depending on the demand and the availability and cost of generating resources at each company within the Southern Company system. These purchases are made in accordance
with the IIC or other contractual agreements, all as approved by the FERC.
Other Operations and Maintenance Expenses
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$43
9.1
In
the first quarter 2022, other operations and maintenance expenses were $517 million compared to $474 million for the corresponding period in 2021. The increase was primarily due to increases of $45 million in transmission and distribution expenses primarily associated with line maintenance and $19 million in generation expenses primarily related to non-outage maintenance costs, partially offset by $17 million in gains from sales of integrated transmission system assets and a $9 million reduction in billing adjustments with integrated transmission system owners largely resulting from a terminated transmission service agreement.
Depreciation and Amortization
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$13
3.8
In the first quarter 2022, depreciation and amortization was $351 million compared to $338 million for the corresponding period in 2021. The increase was primarily due to additional plant in service.
Taxes Other Than Income Taxes
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$9
7.8
In the first quarter 2022, taxes other than income taxes was $125 million compared to $116 million for the corresponding period in 2021. The increase was primarily due to an increase in municipal franchise fees largely related to higher retail revenues.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Estimated Loss on Plant Vogtle Units 3 and 4
First Quarter 2022 vs. First
Quarter 2021
(change in millions)
(% change)
$(48)
N/M
N/M - Not meaningful
In the first quarter 2021, a $48 million estimated probable loss on Plant Vogtle Units 3 and 4 was recorded at Georgia Power. The loss reflects revisions to the total project capital cost forecast to complete construction and start-up of Plant Vogtle Units 3 and 4. See Note (B)
to the Condensed Financial Statements herein and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.
Other Income (Expense), Net
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$9
22.0
In
the first quarter 2022, other income (expense), net was $50 million compared to $41 million for the corresponding period in 2021. The increase was primarily due to increases of $3 million in customer charges related to contributions in aid of construction and $3 million in non-service cost-related retirement benefits income. See Note (H) to the Condensed Financial Statements herein for additional information on retirement benefits.
Income Taxes
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$12
66.7
In
the first quarter 2022, income taxes were $30 million compared to $18 million for the corresponding period in 2021. The increase was primarily due to the reduction in pre-tax earnings in the first quarter 2021 resulting from a charge associated with the construction of Plant Vogtle Units 3 and 4. See Note (B) to the Condensed Financial Statements herein and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.
Mississippi Power
Net Income
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(3)
(6.7)
Mississippi Power's net income in the first quarter 2022 was$42 million compared to $45 million for the corresponding period in 2021. The decrease was primarily due to an increase in operations and maintenance expenses, largely offset by an increase
in revenues.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Retail Revenues
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$13
6.4
In the first quarter 2022, retail revenues were $217 million compared to $204 million for the corresponding period in 2021.
Details of the changes in retail revenues were as follows:
First
Quarter 2022
(in millions)
(% change)
Retail – prior year
$
204
Estimated change resulting from –
Rates
and pricing
3
1.5
%
Sales growth
1
0.5
Weather
(2)
(1.0)
Fuel
and other cost recovery
11
5.4
Retail – current year
$
217
6.4
%
Revenues associated with changes in rates and pricing increased in the first quarter 2022 when compared
to the corresponding period in 2021 primarily due to new PEP rates that became effective for the first billing cycle of April 2021. See Note 2 to the financial statements under "Mississippi Power – Performance Evaluation Plan" in Item 8 of the Form 10-K for additional information.
Revenues attributable to changes in sales increased in the first quarter 2022 when compared to the corresponding period in 2021. Weather-adjusted residential and commercial KWH sales increased 0.8% and 2.9%, respectively, in the first quarter 2022 when compared to the corresponding period in 2021 due to increased customer usage and customer growth. Industrial KWH sales decreased 0.1% in the
first quarter 2022 when compared to the corresponding period in 2021.
Fuel and other cost recovery revenues increased in the first quarter 2022 when compared to the corresponding period in 2021 primarily as a result of higher recoverable fuel costs. Recoverable fuel costs include fuel and purchased power expenses reduced by the fuel portion of wholesale revenues from energy sold to customers outside Mississippi Power's service territory. Electric rates include provisions to adjust billings for fluctuations in fuel costs, including the energy component of purchased power costs. Under these provisions, fuel revenues generally equal fuel expenses, including the energy component of purchased power costs, and do not affect net income.
Wholesale Revenues – Non-Affiliates
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$5
7.9
In the first quarter 2022, wholesale revenues from sales to non-affiliates were $68 million compared to $63 million for the corresponding period in 2021. The increase was primarily due to higher fuel costs and customer usage.
Wholesale
revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Mississippi Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are
MANAGEMENT'S
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. In addition, Mississippi Power provides service under long-term contracts with rural electric cooperative associations and municipalities located in southeastern Mississippi under cost-based electric tariffs which are subject to regulation by the FERC. See Note 2 to the financial statements under "Mississippi Power" in Item 8 of the Form 10-K for additional information.
Wholesale Revenues – Affiliates
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$9
27.3
In the first quarter 2022, wholesale revenues from sales to affiliates were $42 million compared to $33 million for the corresponding period in 2021. The increase was primarily due to an increase of $14 million associated with higher natural gas prices, partially offset by a decrease of $4 million associated
with lower KWH sales.
Wholesale revenues from sales to affiliated companies will vary depending on demand and the availability and cost of generating resources at each company. These affiliate sales are made in accordance with the IIC, as approved by the FERC. These transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost.
Fuel and Purchased Power Expenses
First
Quarter 2022 vs.
First Quarter 2021
(change in millions)
(% change)
Fuel
$
26
24.5
Purchased power
—
—
Total
fuel and purchased power expenses
$
26
In the first quarter 2022, total fuel and purchased power expenses were $132 million compared to $106 million for the corresponding period in 2021. The increase was primarily due to a $33 million increase in the average cost of fuel, partially offset by a $7 million decrease associated with the volume of KWHs generated and purchased.
Fuel and purchased power energy transactions do not have a significant impact on earnings since energy
expenses are generally offset by energy revenues through Mississippi Power's fuel cost recovery clause.
Details of Mississippi Power's generation and purchased power were as follows:
First Quarter 2022
First Quarter 2021
Total
generation (in millions of KWHs)
4,074
4,324
Total purchased power (in millions of KWHs)
120
121
Sources of generation (percent) –
Gas
92
91
Coal
8
9
Cost
of fuel, generated (in cents per net KWH)–
Gas
3.30
2.41
Coal
3.74
3.17
Average
cost of fuel, generated (in cents per net KWH)
3.34
2.49
Average cost of purchased power (in cents per net KWH)
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Fuel
In the first quarter 2022, fuel expense was $132 million compared to $106 million for the corresponding period in 2021. The increase was due to a 36.9% increase in the average cost of natural gas per KWH generated and an 18.0% increase in the average cost of coal per KWHs generated, partially offset by a 16.9% decrease in the volume of KWHs generated by coal and a 6.1% decrease in the volume of KWHs generated by natural gas.
Other
Operations and Maintenance Expenses
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$8
11.8
In
the first quarter 2022, other operations and maintenance expenses were $76 million compared to $68 million for the corresponding period in 2021. The increase was primarily due to increases of $4 million associated with the Kemper County energy facility (primarily related to additional dismantlement activities and lower salvage proceeds in 2022 as compared to 2021) and $3 million in distribution and transmission operations and maintenance activities.
Southern Power
Net Income Attributable to Southern Power
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(25)
(25.8)
Net income attributable to Southern Power in the first quarter 2022 was $72 million compared to $97 million for the corresponding period in 2021. The decrease was primarily due to gains from the contributions of wind turbine equipment to various equity method investments in the first quarter 2021.
Operating
Revenues
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$99
22.5
Total
operating revenues include PPA capacity revenues, which are derived primarily from long-term contracts involving natural gas facilities, and PPA energy revenues from Southern Power's generation facilities. To the extent Southern Power has capacity not contracted under a PPA, it may sell power into an accessible wholesale market, or, to the extent those generation assets are part of the FERC-approved IIC, it may sell power into the Southern Company power pool.
Natural Gas Capacity and Energy Revenue
Capacity revenues generally represent the greatest contribution to operating income and are designed to provide recovery of fixed costs plus a return on investment.
Energy is generally sold at variable cost or is indexed to published natural gas indices. Energy revenues will vary depending on the energy demand of Southern Power's customers and
their generation capacity, as well as the market prices of wholesale energy compared to the cost of Southern Power's energy. Energy revenues also include fees for support services, fuel storage, and unit start charges. Increases and decreases in energy revenues under PPAs that are driven by fuel or purchased power prices are accompanied by an increase or decrease in fuel and purchased power costs and do not have a significant impact on net income.
MANAGEMENT'S
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Solar and Wind Energy Revenue
Southern Power's energy sales from solar and wind generating facilities are predominantly through long-term PPAs that do not have capacity revenue. Customers either purchase the energy output of a dedicated renewable facility through an energy charge or pay a fixed price related to the energy generated from the respective facility and sold to the grid. As a result, Southern Power's ability to recover fixed and variable operations and maintenance expenses is dependent upon the level of energy generated from these facilities, which can be impacted by weather conditions, equipment performance, transmission constraints, and other factors.
See FUTURE EARNINGS POTENTIAL – "Southern Power's
Power Sales Agreements" in Item 7 of the Form 10-K for additional information regarding Southern Power's PPAs.
Operating Revenues Details
Details of Southern Power's operating revenues were as follows:
First Quarter 2022
First
Quarter 2021
(in millions)
PPA capacity revenues
$
102
$
96
PPA energy revenues
345
245
Total
PPA revenues
447
341
Non-PPA revenues
84
95
Other revenues
8
4
Total
operating revenues
$
539
$
440
In the first quarter 2022, total operating revenues were $539 million, reflecting a $99 million, or 23%, increase from the corresponding period in 2021. The increase in operating revenues was primarily due to the following:
•PPA capacity revenues increased $6 million, or 6%, primarily due to new natural gas PPAs and increased capacity sales under existing natural gas PPAs, partially offset by the contractual expiration of natural gas
PPAs.
•PPA energy revenues increased $100 million, or 41%, primarily due to a $59 million increase in sales under existing natural gas PPAs resulting from a $37 million increase in the price of fuel and purchased power and a $22 million increase in the volume of KWHs sold. Also contributing to the increase was a $47 million increase in sales associated with new natural gas PPAs, partially offset by a $13 million decrease due to the contractual expiration of natural gas PPAs.
•Non-PPA revenues decreased $11 million, or 12%, primarily due to a $12 million decrease in the volume of KWHs sold through short-term sales.
Fuel and Purchased Power Expenses
Details
of Southern Power's generation and purchased power were as follows:
First Quarter 2022
First Quarter 2021
(in billions of KWHs)
Generation
11.0
9.4
Purchased
power
0.5
0.6
Total generation and purchased power
11.5
10.0
Total generation and purchased power
(excluding solar, wind, fuel cells, and tolling agreements)
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Southern Power's PPAs for natural gas generation generally provide that the purchasers are responsible for either procuring the fuel (tolling agreements) or reimbursing Southern Power for substantially all of the cost of fuel relating to the energy delivered under such PPAs. Consequently, changes in such fuel costs are generally accompanied by a corresponding change in related fuel revenues and do not have a significant impact on net income. Southern Power is responsible for the cost of fuel for generating units that
are not covered under PPAs. Power from these generating units is sold into the wholesale market or into the Southern Company power pool for capacity owned directly by Southern Power.
Purchased power expenses will vary depending on demand, availability, and the cost of generating resources throughout the Southern Company system and other contract resources. Load requirements are submitted to the Southern Company power pool on an hourly basis and are fulfilled with the lowest cost alternative, whether that is generation owned by Southern Power, an affiliate company, or external parties. Such purchased power costs are generally recovered through PPA revenues.
Details of Southern Power's fuel and purchased power expenses were as follows:
First
Quarter 2022 vs.
First Quarter 2021
(change in millions)
(% change)
Fuel
$
91
64.5
Purchased power
1
5.0
Total
fuel and purchased power expenses
$
92
In the first quarter 2022, total fuel and purchased power expenses increased $92 million, or 57%, compared to the corresponding period in 2021 primarily due to a $68 million increase in the average cost of fuel per KWH generated and a $23 million increase associated with the volume of KWHs generated.
Gain on Dispositions, Net
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(37)
(94.9)
In the first quarter 2022, gain on dispositions, net was $2 million compared to $39 million for the corresponding period in 2021. The decrease primarily resulted from gains associated with contributions of wind turbine equipment to various equity method investments in the first quarter 2021. See Note 15 to the financial
statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K and Note (E) to the Condensed Financial Statements under "Southern Power" herein for additional information.
Net Loss Attributable to Noncontrolling Interests
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$13
40.6
In
the first quarter 2022, net loss attributable to noncontrolling interests was $45 million compared to $32 million for the corresponding period in 2021. The increased loss was primarily due to loss allocations to the partners in the Garland and Tranquillity battery energy storage facilities and higher HLBV loss allocations to wind tax equity partners, including new partnerships entered into during 2021. The increased loss allocations were partially offset by higher income allocations to solar equity partners.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Southern Company Gas
Operating Metrics
Southern Company Gas continues to focus on several operating metrics, including Heating Degree Days, customer count, and volumes of natural gas sold.
Southern Company Gas measures weather and the effect on its business using Heating Degree Days. Generally, increased Heating Degree Days result in higher demand for natural gas on Southern Company Gas' distribution system. Southern Company Gas has various regulatory mechanisms, such as weather and revenue normalization and straight-fixed-variable rate design, which limit its exposure
to weather changes within typical ranges in each of its utility's respective service territory. Southern Company Gas also utilizes weather hedges to limit the negative income impacts in the event of warmer-than-normal weather.
The number of customers served by gas distribution operations and gas marketing services can be impacted by natural gas prices, economic conditions, and competition from alternative fuels. Gas distribution operations and gas marketing services' customers are primarily located in Georgia and Illinois.
Southern Company Gas' natural gas volume metrics for gas distribution operations and gas marketing services illustrate the effects of weather and customer demand for natural gas.
Seasonality of Results
During the Heating Season, natural gas usage and operating revenues are generally
higher as more customers are connected to the gas distribution systems and natural gas usage is higher in periods of colder weather. Prior to the sale of Sequent on July 1, 2021, wholesale gas services' operating revenues occasionally were impacted due to peak usage by power generators in response to summer energy demands. Southern Company Gas' base operating expenses, excluding cost of natural gas, bad debt expense, and certain incentive compensation costs, are incurred relatively evenly throughout the year. Seasonality also affects the comparison of certain balance sheet items across quarters, including receivables, unbilled revenues, natural gas for sale, and notes payable. However, these items are comparable when reviewing Southern Company Gas' annual results. Thus, Southern Company Gas' operating results for the interim periods presented are not necessarily indicative of annual results and can vary significantly
from quarter to quarter.
Net Income
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(79)
(19.8)
In
the first quarter 2022, net income was $319 million compared to $398 million for the corresponding period in 2021. The first quarter 2021 results include $126 million of net income from Sequent, which was sold on July 1, 2021. Net income increased $31 million at gas distribution operations primarily due to base rate increases and continued investment in infrastructure replacement and $10 million at gas marketing services primarily related to higher commodity prices and higher sales to commercial customers. See Notes 2 and 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.
Natural Gas Revenues, including Alternative Revenue Programs
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$364
21.5
In the first quarter 2022, natural gas revenues, including alternative revenue programs, were $2.1 billion compared to $1.7 billion for the corresponding period in 2021.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Details of the changes in natural gas revenues, including alternative revenue programs, were as follows:
First
Quarter 2022
(in millions)
(% change)
Natural gas revenues – prior year
$
1,694
Estimated change resulting from –
Infrastructure
replacement programs and base rate changes
86
5.1
%
Gas costs and other cost recovery
544
32.1
Gas marketing services
18
1.1
Wholesale
gas services
(297)
(17.5)
Other
13
0.7
Natural
gas revenues – current year
$
2,058
21.5
%
Revenues from infrastructure replacement programs and base rate changes increased in the first quarter 2022 compared to the corresponding period in 2021 primarily due to rate increases at Atlanta Gas Light and Chattanooga Gas and continued investment in infrastructure replacement. See Note 2 to the financial statements under "Southern Company Gas – Rate Proceedings" in Item 8 of the Form 10-K for additional information.
Revenues
associated with gas costs and other cost recovery increased in the first quarter 2022 compared to the corresponding period in 2021 primarily due to higher volumes of natural gas sold and higher natural gas cost recovery. See "Cost of Natural Gas" herein for additional information. Revenue impacts from weather and customer growth are described further below.
Revenues from gas marketing services increased in the first quarter 2022 compared to the corresponding period in 2021 primarily due to higher commodity prices and higher sales to commercial customers.
The change in revenues related to wholesale gas services was due to the sale of Sequent on July 1, 2021. See Note 15 to the financial statements under "Southern
Company Gas" in Item 8 of the Form 10-K for additional information.
Southern Company Gas' natural gas distribution utilities have various regulatory mechanisms that limit their exposure to weather changes. Southern Company Gas also uses hedges for any remaining exposure to warmer-than-normal weather in Illinois for gas distribution operations and in Illinois and Georgia for gas marketing services; therefore, weather typically does not have a significant net income impact. The following table presents Heating Degree Days information for Illinois and Georgia, the primary locations where Southern Company Gas' operations are impacted by weather.
First
Quarter
2022 vs. normal
2022 vs. 2021
Normal(*)
2022
2021
colder (warmer)
colder (warmer)
(in
thousands)
Illinois
2,999
3,007
2,947
0.3
%
2.0
%
Georgia
1,302
1,251
1,254
(3.9)
%
(0.2)
%
(*)Normal
represents the 10-year average from January 1, 2012 through March 31, 2021 for Illinois at Chicago Midway International Airport and for Georgia at Atlanta Hartsfield-Jackson International Airport, based on information obtained from the National Oceanic and Atmospheric Administration, National Climatic Data Center.
(*)Gas
marketing services' customers are primarily located in Georgia and Illinois. March 31, 2021 also includes approximately 50,000 customers in Ohio contracted through an annual auction process to serve for 12 months beginning April 1, 2020.
Southern Company Gas anticipates customer growth and uses a variety of targeted marketing programs to attract new customers and to retain existing customers.
Cost of Natural Gas
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$512
87.8
Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, natural gas distribution rates include provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas and do not affect
net income from gas distribution operations. Cost of natural gas at gas distribution operations represented 90%of the total cost of natural gas in the first quarter 2022. See MANAGEMENT'S DISCUSSION AND ANALYSIS – RESULTS OF OPERATIONS – "Southern Company Gas – Cost of Natural Gas" in Item 7 of the Form 10-K and "Natural Gas Revenues, including Alternative Revenue Programs" herein for additional information.
In the first quarter 2022, cost of natural gas was $1.1 billion compared to $583 million for the corresponding period in 2021. The increase reflects higher gas cost recovery as a result of an 83.9% increase in natural gas prices in the first quarter 2022 compared to the corresponding period in 2021.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
The following table details the volumes of natural gas sold during all periods presented.
First
Quarter
2022 vs. 2021
2022
2021
Gas distribution operations(mmBtu in millions)
Firm
304
288
5.6
%
Interruptible
25
26
(3.8)
Total
329
314
4.8
%
Wholesale
gas services (mmBtu in millions/day)
Daily physical sales(*)
—
7.1
(100.0)
%
Gas marketing services(mmBtu in millions)
Firm:
Georgia
16
19
(15.8)
%
Illinois
3
4
(25.0)
Other
4
6
(33.3)
Interruptible
large commercial and industrial
4
4
—
Total
27
33
(18.2)
%
(*)As a result of the sale
of Sequent, wholesale gas services had no sales in the first quarter 2022. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.
Other Operations and Maintenance Expenses
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$6
2.0
In
the first quarter 2022, other operations and maintenance expenses were $305 million compared to $299 million for the corresponding period in 2021.Excluding $48 million of expenses related to Sequent in 2021, other operations and maintenance expenses increased approximately $54 million. The increase was primarily due to increases of $18 million in compensation and benefit expenses, $16 million in expenses passed through directly to customers primarily related to bad debt at distribution operations, and $6 million in customer account expenses.
Depreciation and Amortization
First
Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$7
5.4
In the first quarter 2022, depreciation and amortization was $137 million compared to $130 million for the corresponding period in 2021. The increase was primarily due to continued infrastructure investments at the natural gas distribution utilities.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Taxes Other Than Income Taxes
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$19
23.5
In
the first quarter 2022, taxes other than income taxes were $100 million compared to $81 million for the corresponding period in 2021. The increase primarily reflects an increase in revenue tax expenses as a result of higher natural gas revenues at Nicor Gas. These revenue tax expenses are passed directly to customers and have no impact on net income.
Other Income (Expense), Net
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$79
125.4
In
the first quarter 2022, other income (expense), net was $16 million of income compared to $63 million of expense for the corresponding period in 2021. The change was largely due to charitable contributions of $75 million in the first quarter 2021.
Income Taxes
First Quarter 2022 vs. First Quarter 2021
(change in millions)
(% change)
$(24)
(19.8)
In
the first quarter 2022, income taxes were $97 million compared to $121 million for the corresponding period in 2021. The decrease was primarily due to a decrease of $40 million at wholesale gas services including Sequent, which was sold on July 1, 2021, partially offset by higher pre-tax earnings from the other segments.
Segment Information
Operating revenues, operating expenses, and net income (loss) for each segment are provided in the table below. See Note (L) to the Condensed Financial Statements under "Southern Company Gas" herein for additional information.
First
Quarter 2022
First Quarter 2021
Operating Revenues
Operating Expenses
Net Income (Loss)
Operating Revenues
Operating Expenses
Net Income (Loss)
(in millions)
(in millions)
Gas
distribution operations
$
1,803
$
1,475
$
214
$
1,200
$
913
$
183
Gas pipeline
investments
8
3
29
8
3
29
Wholesale gas services(*)
—
—
—
298
56
126
Gas
marketing services
243
150
66
195
120
56
All other
16
21
10
7
15
4
Intercompany
eliminations
(12)
(12)
—
(14)
(14)
—
Consolidated
$
2,058
$
1,637
$
319
$
1,694
$
1,093
$
398
(*)As
a result of the sale of Sequent, wholesale gas services is no longer a reportable segment for the first quarter 2022. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Gas
Distribution Operations
Gas distribution operations is the largest component of Southern Company Gas' business and is subject to regulation and oversight by regulatory agencies in each of the states it serves. These agencies approve natural gas rates designed to provide Southern Company Gas with the opportunity to generate revenues to recover the cost of natural gas delivered to its customers and its fixed and variable costs, including depreciation, interest expense, operations and maintenance, taxes, and overhead costs, and to earn a reasonable return on its investments.
With the exception of Atlanta Gas Light, Southern Company Gas' second largest utility that operates in a deregulated natural gas market and has a straight-fixed-variable rate design that minimizes the variability of its revenues based on consumption, the earnings of the natural gas distribution utilities can be affected
by customer consumption patterns that are a function of weather conditions, price levels for natural gas, and general economic conditions that may impact customers' ability to pay for natural gas consumed. Southern Company Gas has various regulatory and other mechanisms, such as weather and revenue normalization mechanisms and weather derivative instruments, that limit its exposure to changes in customer consumption, including weather changes within typical ranges in its natural gas distribution utilities' service territories. See Note 2 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.
In the first quarter 2022, net income increased $31 million, or 16.9%, when compared to the corresponding period in 2021, as described further below:
•Operating
revenues increased $603 million primarily due to higher gas cost recovery, rate increases, and continued investment in infrastructure replacement. Gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas.
•Operating expenses increased $562 million primarily due to a $479 million increase in the cost of gas as a result of higher natural gas prices and higher volumes sold compared to 2021, as well as higher compensation expenses and depreciation resulting from additional assets placed in service. The increase in operating expenses also includes higher costs passed through directly to customers, primarily related to bad debt expenses and revenue taxes.
•Income taxes increased $12 million primarily due to higher pre-tax earnings.
Gas Pipeline
Investments
Gas pipeline investments consists primarily of joint ventures in natural gas pipeline investments including SNG, Dalton Pipeline, and PennEast Pipeline. See Note (E) to the Condensed Financial Statements under "Southern Company Gas" herein for additional information.
Gas Marketing Services
Gas marketing services provides energy-related products and services to natural gas markets and participants in customer choice programs that were approved in various states to increase competition. These programs allow customers to choose their natural gas supplier while the local distribution utility continues to provide distribution and transportation services. Gas marketing services is weather sensitive and uses a variety of hedging strategies, such as weather derivative instruments and other risk management tools, to partially
mitigate potential weather impacts.
In the first quarter 2022, net income increased $10 million, or 17.9%, when compared to the corresponding period in 2021. The increase was primarily due to a $48 million increase in operating revenues as a result of higher commodity prices and higher sales to commercial customers, partially offset by a $30 million increase in operating expenses primarily due to higher cost of natural gas and an increase of $8 million in income taxes as a result of higher pre-tax earnings.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
All Other
All other includes natural gas storage businesses, a renewable natural gas business, AGL Services Company, and Southern Company Gas Capital, as well as various corporate operating expenses that are not allocated to the reportable segments and interest income (expense) associated with affiliate financing arrangements.
In the first quarter 2022, net income increased $6 million, or 150%, when compared to the corresponding period in 2021. Operating revenues increased $9 million primarily related to higher demand fees and favorable hedge gains at the natural gas storage businesses and higher sales from the renewable
natural gas business, partially offset by a $6 million increase in operating expenses primarily due to higher cost of natural gas.
FUTURE EARNINGS POTENTIAL
Each Registrant's results of operations are not necessarily indicative of its future earnings potential. The level of the Registrants' future earnings depends on numerous factors that affect the opportunities, challenges, and risks of the Registrants' primary businesses of selling electricity and/or distributing natural gas, as described further herein.
For the traditional electric operating companies, these factors include the ability to maintain constructive regulatory environments that allow for the timely recovery of prudently-incurred costs during a time of increasing
costs, including those related to projected long-term demand growth, stringent environmental standards, including CCR rules, safety, system reliability and resiliency, fuel, restoration following major storms, and capital expenditures, including constructing new electric generating plants and expanding and improving the transmission and distribution systems; continued customer growth; and the 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 and services. As a result of persistently high inflation, interest rates have been on the rise and are expected to continue rising in the near term. 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 and has sustained the current economic expansion through the first quarter 2022; however,
fiscal support of business and personal incomes is declining. Russia's invasion of Ukraine has intensified supply chain disruptions and heightened uncertainty surrounding the near-term outlook for the broader economy and the economy within the Southern Company system's service territory. 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 the first quarter 2022 when compared to the corresponding period in 2021 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. The impacts of new COVID-19 variants, responses to the COVID-19 pandemic by both customers and governments, inflation, rising interest rates,
and the unresolved geopolitical tensions relating to Russia's invasion of Ukraine could significantly affect the sustainability of current economic growth. See RESULTS OF OPERATIONS herein for information on COVID-19-related impacts on energy demand in the Southern Company system's service territory during the first quarter 2022.
The level of future earnings for Southern Power's competitive wholesale electric business depends on numerous factors including the parameters of the wholesale market and the efficient operation of its wholesale generating assets; Southern Power's ability to execute its growth strategy through the development or acquisition of renewable
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
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.
The
level of future earnings for Southern Company Gas' primary business of distributing natural gas and its complementary businesses in the gas pipeline investments and gas marketing services sectors depends on numerous factors. These factors include the natural gas distribution utilities' ability to maintain constructive regulatory environments that allow for the timely recovery of prudently-incurred costs, including those related to projected long-term demand growth, safety, system reliability and resiliency, natural gas, and capital expenditures, including expanding and improving the natural gas distribution systems; the completion and subsequent operation of ongoing infrastructure and other construction projects; customer creditworthiness; certain policies to limit the use of natural gas, such as the potential across certain parts of the U.S. for state or municipal bans on the use of natural gas; and Southern Company Gas' ability to re-contract storage rates at favorable
prices. The volatility of natural gas prices has an impact on Southern Company Gas' customer rates, its long-term competitive position against other energy sources, and the ability of Southern Company Gas' gas marketing services business to capture value from locational and seasonal spreads. Additionally, changes in commodity prices, primarily driven by tight gas supplies, geopolitical events, and diminished gas production, subject a portion of Southern Company Gas' operations to earnings variability and have recently resulted in higher natural gas prices. Additional economic factors may contribute to this environment. 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, costs and availability of labor and materials in a time of rising costs and supply chain disruptions, and the price elasticity of demand. Demand for electricity and natural gas in the Registrants' service territories is primarily driven by the pace of economic growth or decline that may be affected by changes in regional and global economic conditions, which may impact future earnings.
As part of its ongoing
effort to adapt to changing market conditions, Southern Company continues to evaluate and consider a wide array of potential business strategies. These strategies may include business combinations, partnerships, and acquisitions involving other utility or non-utility businesses or properties, disposition of, or the sale of interests in, certain assets or businesses, internal restructuring, or some combination thereof. Furthermore, Southern Company may engage in new business ventures that arise from competitive and regulatory changes in the utility industry. Pursuit of any of the above strategies, or any combination thereof, may significantly affect the business operations, risks, and financial condition of Southern Company. In addition, Southern Power and Southern Company Gas regularly consider and evaluate joint development arrangements as well as acquisitions and dispositions of businesses and assets as part of their business strategies. See Note 15 to the financial
statements in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements herein for additional information.
For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL in Item 7 of the Form 10-K.
Environmental Matters
See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL –"Environmental Matters" in Item 7 and Note 3 to the financial statements under "Environmental Remediation" in Item 8 of the Form 10-K, as well as Note (C) to the Condensed Financial Statements under "Environmental Remediation"
herein, for additional information.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Regulatory Matters
See Note 2 to the financial
statements in Item 8 of the Form 10-K, OVERVIEW – "Recent Developments" herein, and Note (B) to the Condensed Financial Statements herein for a discussion of regulatory matters related to Alabama Power, Georgia Power, Mississippi Power, and Southern Company Gas, including items that could impact the applicable Registrants' future earnings, cash flows, and/or financial condition.
Construction Programs
The Subsidiary Registrants are engaged in continuous construction programs to accommodate existing and estimated future loads on their respective systems. The Southern Company system strategy continues to include developing and constructing new electric generating facilities, expanding and improving the electric transmission and electric and natural gas distribution
systems, and undertaking projects to comply with environmental laws and regulations.
For the traditional electric operating companies, major generation construction projects are subject to state PSC approval in order to be included in retail rates. The largest construction project currently underway in the Southern Company system is Plant Vogtle Units 3 and 4. See Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information. Also see Note 2 to the financial statements under "Alabama Power – Certificates of Convenience and Necessity" in Item 8 of the Form 10-K for information regarding Alabama Power's construction of Plant Barry Unit 8.
See Note 15 to the financial statements in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements herein under "Southern Power" for information
about costs relating to Southern Power's construction of renewable energy facilities.
Southern Company Gas is engaged in various infrastructure improvement programs designed to update or expand the natural gas distribution systems of the natural gas distribution utilities to improve reliability and meet operational flexibility and growth. The natural gas distribution utilities recover their investment and a return associated with these infrastructure programs through their regulated rates. See Note 2 to the financial statements in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein under "Southern Company Gas" for additional information on Southern Company Gas' construction program.
See FINANCIAL CONDITION AND LIQUIDITY – "Cash Requirements" herein for additional information regarding the Registrants' capital requirements for their construction
programs.
General Litigation and Other Matters
The Registrants are involved in various matters being litigated and/or regulatory and other matters that could affect future earnings, cash flows, and/or financial condition. The ultimate outcome of such pending or potential litigation against each Registrant and any subsidiaries or regulatory and other matters cannot be determined at this time; however, for current proceedings and/or matters not specifically reported herein or in Notes (B) and (C) to the Condensed Financial Statements herein, management does not anticipate that the ultimate liabilities, if any, arising from such current proceedings and/or matters would have a material effect on such Registrant's financial statements. See Notes (B) and (C) to the Condensed
Financial Statements for a discussion of various contingencies, including matters being litigated, regulatory matters, and other matters which may affect future earnings potential.
ACCOUNTING POLICIES
See MANAGEMENT'S DISCUSSION AND ANALYSIS – ACCOUNTING POLICIES in Item 7 of the Form 10-K for a complete discussion of the Registrants' critical accounting policies and estimates, as well as recently issued accounting standards.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
The Registrants prepare their financial statements in accordance with GAAP. Significant accounting policies are described in the notes to the financial statements in Item 8 of the Form 10-K. In the application of these policies, certain estimates are made that may have a material impact on the Registrants' results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements.
FINANCIAL CONDITION AND LIQUIDITY
Overview
See
MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY –"Overview" in Item 7 of the Form 10-K for additional information. The financial condition of each Registrant remained stable at March 31, 2022. The Registrants intend to continue to monitor their access to short-term and long-term capital markets as well as their bank credit arrangements to meet future capital and liquidity needs. See "Cash Requirements,""Sources of Capital," and "Financing Activities" herein for additional information.
At the end of the first quarter 2022, the market price of Southern Company's common stock was $72.51 per share (based on the closing price as reported on the NYSE) and the book value was $26.63 per share, representing a market-to-book ratio of 272%, compared to $68.58, $26.30, and 261%, respectively,
at the end of 2021. Southern Company's common stock dividend for the first quarter 2022 was $0.66 per share compared to $0.64 per share in the first quarter 2021.
Cash Requirements
See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Cash Requirements" in Item 7 of the Form 10-K for a description of the Registrants' significant cash requirements.
The Registrants' significant cash requirements include estimated capital expenditures associated with their construction programs. The construction programs are subject to periodic review and revision, and actual construction costs may vary from these
estimates because of numerous factors. These factors include: changes in business conditions; changes in load projections; changes in environmental laws and regulations; the outcome of any legal challenges to environmental rules; changes in electric generating plants, including unit retirements and replacements and adding or changing fuel sources at existing electric generating units, to meet regulatory requirements; changes in FERC rules and regulations; state regulatory agency approvals; changes in the expected environmental compliance program; changes in legislation and/or regulation; the cost, availability, and efficiency of construction labor, equipment, and materials; project scope and design changes; abnormal weather; delays in construction due to judicial or regulatory action; storm impacts; and the cost of capital. The continued impacts of the COVID-19 pandemic could also impair the ability to develop, construct, and operate facilities, as discussed further
in Item 1A of the Form 10-K. In addition, there can be no assurance that costs related to capital expenditures and AROs will be fully recovered. Additionally, expenditures associated with Southern Power's planned acquisitions may vary due to market opportunities and the execution of its growth strategy. See Note 15 to the financial statements in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements herein under "Southern Power" for additional information regarding Southern Power's plant acquisitions and construction projects.
The construction program of Georgia Power includes Plant Vogtle Units 3 and 4, which includes components based on new technology that only within the last few years began initial operation in the global nuclear industry at this scale and which may be subject to additional revised cost estimates during construction. See Note 2 to the financial statements in Item 8 of the Form
10-K and Note (B) to the Condensed Financial Statements herein under "Georgia Power – Nuclear Construction" for information regarding Plant Vogtle Units 3 and 4 and additional factors that may impact construction expenditures.
Long-term debt maturities and the interest payable on long-term debt each represent a significant cash requirement for the Registrants. See "Financing Activities" herein for information on changes in the Registrants' long-term debt balances since December 31, 2021.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Sources of Capital
See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" in Item 7 of the Form 10-K for additional information. Southern Company intends to meet its future capital needs through operating cash flows, borrowings from financial institutions, and debt and equity issuances. Equity capital can be provided from any combination of Southern Company's stock plans, private placements, or public offerings. With the
exception of the settlement later in 2022 of stock purchase contracts associated with its equity units, Southern Company does not expect to issue any equity in the capital markets through 2026, but may issue equity through its stock plans during this time. See Note 8 to the financial statements under "Equity Units" in Item 8 of the Form 10-K for additional information.
The Subsidiary Registrants plan to obtain the funds to meet their future capital needs from sources similar to those they used in the past, which were primarily from operating cash flows, external securities issuances, borrowings from financial institutions, and equity contributions from Southern Company. In addition, Southern Power plans to utilize tax equity partnership contributions (as discussed further herein).
The amount, type, and timing of any financings in 2022, as well as in subsequent years, will be
contingent on investment opportunities and the Registrants' capital requirements and will depend upon prevailing market conditions, regulatory approvals (for certain of the Subsidiary Registrants), and other factors. See "Cash Requirements" and "Financing Activities" herein for additional information.
Southern Power utilizes tax equity partnerships as one of its financing sources, where the tax partner takes significantly all of the federal tax benefits. These tax equity partnerships are consolidated in Southern Power's financial statements and are accounted for using HLBV methodology to allocate partnership gains and losses. During the first quarter 2022, Southern Power obtained tax equity funding for existing tax equity partnerships totaling $51 million. See Note 1 to the financial statements under "General" in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements under "Southern
Power" herein for additional information.
By regulation, Nicor Gas is restricted, to the extent of its retained earnings balance, in the amount it can dividend or loan to affiliates and is not permitted to make money pool loans to affiliates. At March 31, 2022, the amount of subsidiary retained earnings restricted to dividend totaled $1.4 billion. This restriction did not impact Southern Company Gas' ability to meet its cash obligations, nor does management expect such restriction to materially impact Southern Company Gas' ability to meet its currently anticipated cash obligations.
Certain Registrants' current liabilities frequently exceed their current assets because of long-term debt maturities and the periodic use of short-term debt as a funding source, as well as significant seasonal fluctuations in cash needs. The Registrants
generally plan to refinance long-term debt as it matures. The following table shows the amount by which current liabilities exceeded current assets at March 31, 2022 for the applicable Registrants:
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.
(a)At
March 31, 2022, Southern Power also had two continuing letters of credit facilities for standby letters of credit, of which $30 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 March 31, 2022 was approximately $1.5 billion (comprised of approximately $789 million at Alabama Power, $672 million at Georgia Power, and $34 million at Mississippi Power). In addition, at March 31, 2022, Georgia Power had approximately $330 million of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months.
See Note 8 to the financial statements in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements herein under "Bank Credit Arrangements" for additional information.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Short-term Borrowings
The Registrants, Nicor Gas, and SEGCO make short-term borrowings primarily through commercial paper programs that have the liquidity support of the committed bank credit arrangements described above. Southern Power's subsidiaries are not issuers or obligors under its commercial paper program. Commercial paper and short-term bank term loans are included in notes payable in the balance sheets. Details of the Registrants' short-term borrowings were as follows:
(*)Average
and maximum amounts are based upon daily balances during the three-month period ended March 31, 2022.
Analysis of Cash Flows
Net cash flows provided from (used for) operating, investing, and financing activities for the three months ended March 31, 2022 and 2021 are presented in the following table:
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Southern Company
Net cash provided from operating activities increased $350 million for the three months ended March 31, 2022 as compared to the corresponding period in 2021 primarily due to increased natural gas cost recovery at the natural gas distribution utilities and the timing of vendor payments, partially offset by the timing of customer receivable collections.
The net cash
used for investing activities for the three months ended March 31, 2022 was primarily related to the Subsidiary Registrants' construction programs.
The net cash used for financing activities for the three months ended March 31, 2022 was primarily related to common stock dividend payments and net redemptions of long-term debt, largely offset by an increase in short-term debt.
Alabama Power
Net cash provided from operating activities decreased $60 million for the three months ended March 31, 2022 as compared to the corresponding period in 2021 primarily due to the timing of
customer receivable collections, decreased fuel cost recovery, and the timing of fuel stock purchases, partially offset by the timing of vendor payments.
The net cash used for investing activities for the three months ended March 31, 2022 was primarily related to gross property additions.
The net cash provided from financing activities for the three months ended March 31, 2022 was primarily related to capital contributions from Southern Company and the net issuance of long-term debt, partially offset by common stock dividend payments.
Georgia Power
Net cash provided from operating
activities decreased $128 million for the three months ended March 31, 2022 as compared to the corresponding period in 2021 primarily due to the timing of customer receivable collections and decreased fuel cost recovery, partially offset by the timing of vendor payments.
The net cash used for investing activities for the three months ended March 31, 2022 was primarily related to gross property additions, including a total of approximately $240 million related to the construction of Plant Vogtle Units 3 and 4. See Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information on construction of Plant Vogtle Units 3 and 4.
The net cash provided from financing activities for the three months ended March 31,
2022 was primarily related to an increase in short-term borrowings and capital contributions from Southern Company, partially offset by common stock dividend payments and the redemption of senior notes.
Mississippi Power
Net cash used for operating activities decreased $22 million for the three months ended March 31, 2022 as compared to the corresponding period in 2021 primarily due to the timing of vendor payments.
The net cash used for investing activities for the three months ended March 31, 2022 was primarily related to gross property additions.
The net cash provided from
financing activities for the three months ended March 31, 2022 was primarily related to capital contributions from Southern Company and an increase in short-term borrowings, partially offset by common stock dividend payments.
MANAGEMENT'S DISCUSSION AND
ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Southern Power
Net cash provided from operating activities decreased $70 million for the three months ended March 31, 2022 as compared to the corresponding period in 2021 primarily due to the timing of vendor payments and customer receivable collections.
The net cash used for investing activities for the three months ended March 31, 2022 was primarily related to construction payments. See Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information.
The net cash used for financing activities for the three months ended March 31,
2022 was primarily related to common stock dividend payments and a net capital distribution to noncontrolling interests.
Southern Company Gas
Net cash provided from operating activities increased $474 million for the three months ended March 31, 2022 as compared to the corresponding period in 2021 primarily due to increased natural gas cost recovery, partially offset by the timing of customer receivable collections.
The net cash used for investing activities for the three months ended March 31, 2022 was primarily related to construction of transportation and distribution
assets recovered through base rates and infrastructure investment recovered through replacement programs at gas distribution operations.
The net cash used for financing activities for the three months ended March 31, 2022 was primarily related to net repayments of short-term debt and common stock dividend payments, partially offset by capital contributions from Southern Company.
Significant Balance Sheet Changes
Southern Company
Significant balance sheet changes for the three months ended March 31,
2022 included:
•an increase of $0.9 billion in notes payable due to an increase in short-term bank debt and commercial paper borrowings;
•an increase of $0.7 billion in total property, plant, and equipment primarily related to the Subsidiary Registrants' construction programs;
•increases of $0.6 billion in accumulated deferred income taxes and $0.4 billion in prepaid expenses primarily related to the expected utilization of ITCs in 2022;
•a decrease of $0.5 billion in accrued compensation due to the timing of payments; and
•a decrease of $0.5 billion in long-term debt (including securities due within one year) primarily due to the
redemption of senior notes.
See "Financing Activities" herein and Note (G) to the Condensed Financial Statements herein for additional information.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS
OF OPERATIONS (Continued)
Alabama Power
Significant balance sheet changes for the three months ended March 31, 2022 included:
•an increase of $719 million in common stockholder's equity primarily due to capital contributions from Southern Company;
•an increase of $293 million in cash and cash equivalents, as discussed further under "Analysis of Cash Flows – Alabama Power" herein;
•an increase of $161 million in total property, plant, and equipment primarily related to construction of distribution and transmission facilities, construction of Plant Barry Unit 8, and the installation of equipment to comply with environmental
standards; and
•an increase of $145 million in long-term debt (including securities due within one year) primarily due to a net increase in outstanding senior notes.
See "Financing Activities – Alabama Power" herein for additional information.
Georgia Power
Significant balance sheet changes for the three months ended March 31, 2022 included:
•an increase of $860 million in notes payable due to an increase in short-term bank debt and commercial paper borrowings;
•an
increase of $499 million in total property, plant, and equipment primarily related to the construction of generation, transmission, and distribution facilities, including $303 million for Plant Vogtle Units 3 and 4;
•a decrease of $421 million in long-term debt (including securities due within one year) primarily due to the redemption of senior notes; and
•an increase of $415 million in common stockholder's equity primarily due to capital contributions from Southern Company.
See "Financing Activities – Georgia Power" herein and Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information.
Mississippi
Power
Significant balance sheet changes for the three months ended March 31, 2022 included:
•increases of $66 million in assets from risk management activities and $61 million in other regulatory liabilities, current primarily due to unrealized gains on short-term energy-related derivatives;
•a decrease of $64 million in accrued taxes primarily due to the payment of ad valorem taxes; and
•a decrease of $52 million in cash and cash equivalents, as discussed further under "Analysis of Cash Flows – Mississippi Power" herein.
See Note (J) to the Condensed Financial Statements herein for additional information.
Southern
Power
Significant balance sheet changes for the three months ended March 31, 2022 included increases of $441 million in prepaid income taxes and $446 million in accumulated deferred income tax liabilities primarily related to the expected utilization of ITCs in 2022. See Note (G) to the Condensed Financial Statements herein for additional information.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Southern Company Gas
Significant balance sheet changes for the three months ended March 31, 2022 included:
•a decrease of $677 million in notes payable due to repayments of short-term debt and commercial paper borrowings;
•an increase of $259 million in common stockholder's equity related to net income and capital contributions from Southern Company, partially offset by dividends paid to Southern Company;
•a
decrease of $241 million in natural gas for sale primarily due to higher volumes of natural gas sold;
•an increase of $209 million in temporary LIFO liquidation due to use of stored natural gas;
•a decrease of $181 million in other regulatory assets, deferred primarily due to a $163 million reduction in natural gas cost under recovery;
•an increase of $147 million in total property, plant, and equipment primarily related to the construction of transportation and distribution assets recovered through base rates and infrastructure investment recovered through replacement programs; and
•an increase of $141 million in customer accounts receivable due to the timing of collections.
See
"Financing Activities – Southern Company Gas" herein and Note (B) to the Condensed Financial Statements herein for additional information.
Financing Activities
The following table outlines the Registrants' long-term debt financing activities for the first three months of 2022:
Maturities
and Redemptions
Company
Senior Note Issuances
Senior Notes
Other Long-Term Debt(*)
(in millions)
Alabama Power
$
700
$
550
$
—
Georgia
Power
—
400
24
Other
—
—
3
Southern
Company
$
700
$
950
$
27
(*)Includes reductions in finance lease obligations resulting from cash payments under finance leases and, for Georgia Power, principal amortization payments totaling $24 million for FFB borrowings. See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K for additional information.
Except
as otherwise described herein, the Registrants used the proceeds of debt issuances for their redemptions and maturities shown in the table above, to repay short-term indebtedness, and for general corporate purposes, including working capital. The Subsidiary Registrants also used the proceeds for their construction programs.
In addition to any financings that may be necessary to meet capital requirements and contractual obligations, the Registrants plan to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.
Southern Company
During the first quarter 2022, Southern Company issued approximately 2.6 million shares
of common stock primarily through employee equity compensation plans and received proceeds of approximately $38 million.
In March 2022, Southern Company entered into a $400 million short-term floating rate bank loan bearing interest based on term SOFR.
MANAGEMENT'S
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Alabama Power
In February 2022, Alabama Power redeemed all $550 million aggregate principal amount of its Series 2017A 2.45% Senior Notes due March 30, 2022.
In March 2022, Alabama Power issued $700 million aggregate principal amount of Series 2022A 3.05% Senior Notes due March 15, 2032.
Georgia Power
In January 2022, Georgia Power redeemed all $400 million aggregate principal amount of its Series 2012B 2.85% Senior
Notes due May 15, 2022.
In February 2022, Georgia Power borrowed $250 million pursuant to a short-term uncommitted bank credit arrangement bearing interest at a rate agreed upon by Georgia Power and the bank from time to time and payable on demand, following specified notice by the bank.
In March 2022, Georgia Power entered into a $200 million short-term floating rate bank loan bearing interest based on term SOFR.
Subsequent to March 31, 2022, Georgia Power entered into an additional $200 million short-term floating rate bank loan bearing interest based on term SOFR.
Mississippi
Power
In March 2022, Mississippi Power borrowed $20 million (short term) pursuant to its $125 million revolving credit arrangement bearing interest based on term SOFR.
Southern Company Gas
During the first quarter 2022, Nicor Gas repaid one of its three $100 million short-term floating rate bank loans entered into in March 2021. Nicor Gas repaid $50 million of one of the other loans and increased the borrowing amount under the other loan to $150 million. In addition, both loans were renewed and amended to extend the maturity dates and change the interest rate provisions so the loans bear interest based on term SOFR.
Subsequent to March
31, 2022, Atlanta Gas Light repaid at maturity $36 million aggregate principal amount of medium-term notes with a weighted average interest rate of 8.65%.
Credit Rating Risk
At March 31, 2022, the Registrants did not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade.
There are certain contracts that could require collateral, but not accelerated payment, in the event of a credit rating change of certain Registrants to BBB and/or Baa2 or below. These contracts are primarily for physical electricity and natural gas purchases and sales, fuel purchases, fuel transportation and storage,
energy price risk management, transmission, interest rate management, and, for Georgia Power, construction of new generation at Plant Vogtle Units 3 and 4.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
The maximum potential collateral requirements under these contracts at March 31,
2022 were as follows:
Credit Ratings
Southern Company(*)
Alabama Power
Georgia Power
Mississippi Power
Southern
Power(*)
Southern
Company Gas
(in millions)
At BBB and/or Baa2
$
37
$
1
$
—
$
—
$
36
$
—
At BBB- and/or Baa3
427
2
61
1
365
—
At
BB+ and/or Ba1 or below
1,946
405
924
305
1,202
5
(*)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 March 31, 2022.
The amounts in the previous table for the traditional electric operating companies and Southern Power include certain agreements that could require collateral if either Alabama Power or Georgia Power has a credit rating change to below investment grade. Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. Additionally, a credit rating downgrade could impact the ability of the Registrants to access capital markets and would be likely to impact the cost at which they do so.
On February 22, 2022, Fitch downgraded the senior unsecured long-term debt rating of Georgia Power to BBB+ from A- with a stable outlook.
Also on February 22, 2022,
Fitch revised the ratings outlook of Southern Company, Alabama Power, Southern Power, Nicor Gas, and SEGCO to negative from stable.
Item 3. Quantitative and Qualitative Disclosures About Market Risk.
During the three months ended March 31,
2022, there were no material changes to Southern Company's, Alabama Power's, Georgia Power's, Mississippi Power's, Southern Power's, or Southern Company Gas' disclosures about market risk. For an in-depth discussion of each Registrant's market risks, see MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Market Price Risk" in Item 7 of the Form 10-K and Note 1 to the financial statements under "Financial Instruments" and Notes 13 and 14 to the financial statements in Item 8 of the Form 10-K, as well as Notes (I) and (J) to the Condensed Financial Statements herein.
Item 4. Controls and Procedures.
(a)Evaluation of disclosure controls and procedures.
As
of the end of the period covered by this Quarterly Report on Form 10-Q, Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas conducted separate evaluations under the supervision and with the participation of each company's management, including the Chief Executive Officer and the Chief Financial Officer, of the effectiveness of the design and operation of the disclosure controls and procedures (as defined in Sections 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended). Based upon these evaluations, the Chief Executive Officer and the Chief Financial Officer, in each case, concluded that the disclosure controls and procedures are effective.
(b) Changes in internal controls over financial reporting.
There have been no changes in Southern Power's or Southern Company Gas' internal control over financial
reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended) during the first quarter 2022 that have materially affected or are reasonably likely to materially affect Southern Power's or Southern Company Gas' internal control over financial reporting.
In January 2022, Southern Company, Alabama Power, Georgia Power, and Mississippi Power implemented new financial accounting and reporting applications. As a result, there were certain changes to processes and procedures, which resulted in changes to Southern Company's, Alabama Power's, Georgia Power's, and Mississippi Power's internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended). These changes include automation of certain previously manual controls. These changes in internal controls were not made in response to any
identified internal control deficiency.
See the Notes to the Condensed
Financial Statements herein for information regarding certain legal and administrative proceedings in which the Registrants are involved. The Registrants' threshold for disclosing material environmental legal proceedings involving a governmental authority where potential monetary sanctions are involved is $1 million.
Item 1A. Risk Factors.
See RISK FACTORS in Item 1A of the Form 10-K for a discussion of the risk factors of the Registrants. There have been no material changes to these risk factors from those previously disclosed in the Form 10-K.
Item 6. Exhibits.
The
exhibits below with an asterisk (*) preceding the exhibit number are filed herewith. The remaining exhibits have previously been filed with the SEC and are incorporated herein by reference. The exhibits marked with a pound sign (#) are management contracts or compensatory plans or arrangements.
(4) Instruments Describing Rights of Security Holders, Including Indentures
Form of Terms for Named Executive Officer Equity Awards Granted under The Southern Company 2021 Equity and Incentive Compensation Plan. See Exhibit 10(a)1 herein.
(b)2
-
Fifth Amendment to The Southern Company Employee Savings Plan. See Exhibit 10(a)2 herein.
(b)3
-
Sixth
Amendment to The Southern Company Employee Savings Plan. See Exhibit 10(a)3 herein.
#
(b)4
-
Fourth Amendment to The Southern Company Deferred Compensation Plan. See Exhibit 10(a)4 herein.
#
(b)5
-
Eighth
Amendment to The Southern Company Supplemental Benefit Plan. See Exhibit 10(a)5 herein.
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Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.
THE
SOUTHERN COMPANY
By
Thomas A. Fanning
Chairman, President, and Chief Executive Officer
(Principal Executive Officer)
By
Daniel S. Tucker
Executive Vice President and Chief Financial Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.
ALABAMA
POWER COMPANY
By
Mark A. Crosswhite
Chairman, President, and Chief Executive Officer
(Principal Executive Officer)
By
Philip C. Raymond
Executive Vice President, Chief Financial Officer, and Treasurer
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.
GEORGIA
POWER COMPANY
By
Christopher C. Womack
Chairman, President, and Chief Executive Officer
(Principal Executive Officer)
By
Aaron P. Abramovitz
Executive Vice President, Chief Financial Officer, and
Treasurer
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.
MISSISSIPPI
POWER COMPANY
By
Anthony L. Wilson
Chairman, President, and Chief Executive Officer
(Principal Executive Officer)
By
Moses H. Feagin
Senior
Vice President, Chief Financial Officer, and Treasurer
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The
signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.
SOUTHERN POWER COMPANY
By
Christopher Cummiskey
Chairman
and Chief Executive Officer
(Principal Executive Officer)
By
Elliott L. Spencer
Senior Vice President, Chief Financial Officer, and Treasurer
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.
SOUTHERN
COMPANY GAS
By
Kimberly S. Greene
Chairman, President, and Chief Executive Officer
(Principal Executive Officer)
By
David P. Poroch
Executive
Vice President, Chief Financial Officer, and Treasurer
