NOTES TO THE CONDENSED FINANCIAL STATEMENTS
FOR
THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES
ALABAMA POWER COMPANY
GEORGIA POWER COMPANY
MISSISSIPPI POWER COMPANY
SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES
SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES
(UNAUDITED)
INDEX TO THE NOTES TO THE CONDENSED FINANCIAL STATEMENTS
INDEX TO APPLICABLE NOTES TO FINANCIAL STATEMENTS BY REGISTRANT
The following unaudited notes to the condensed financial statements are a combined presentation; however, information contained herein relating to any individual Registrant is filed by such Registrant on its own behalf and each Registrant makes no representation as to information related to the other Registrants. The list below indicates the Registrants to which each footnote applies.
| | | | | |
| Registrant | Applicable Notes |
| Southern Company | A, B, C, D, E, F, G, H, I, J, K, L |
| Alabama Power | A, B, C, D, F, G, H, I, J |
| Georgia Power | A, B, C, D, F, G, H, I, J |
| Mississippi Power | A, B, C, D, F, G, H, I, J |
| Southern Power | A, C, D, E, F, G, H, I, J, K |
| Southern Company Gas | A, B, C, D, E, F, G, H, I, J, K, L |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS
(UNAUDITED)
(A) INTRODUCTION
The condensed quarterly financial statements of each Registrant included herein have been prepared by such Registrant, without audit, pursuant to the rules and regulations of the SEC. The Condensed Balance Sheets at December 31, 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 June 30, 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.
Certain prior year data presented in the financial statements have been reclassified to conform to the current year presentation. These reclassifications had no impact on the overall results of operations, financial position, or cash flows of any Registrant.
Goodwill and Other Intangible Assets
Goodwill at June 30, 2022 and December 31, 2021 was as follows:
| | | | | | |
| Goodwill | |
| (in millions) |
| Southern Company | $ | 5,280 | | |
| Southern Company Gas: | | |
| Gas distribution operations | $ | 4,034 | | |
| Gas marketing services | 981 | | |
| Southern Company Gas total | $ | 5,015 | | |
Goodwill is not amortized, but is subject to an annual impairment test during the fourth quarter of each year, or more frequently if impairment indicators arise.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Other intangible assets were as follows:
| | | | | | | | | | | | | | | | | | | | | | | |
| At June 30, 2022 | | At December 31, 2021 |
| Gross Carrying Amount | Accumulated Amortization | Other
Intangible Assets, Net | | Gross Carrying Amount | Accumulated Amortization | Other
Intangible Assets, Net |
| (in millions) | | (in millions) |
| Southern Company | | | | | | | |
| Other intangible assets subject to amortization: | | | | | | | |
| Customer relationships | $ | 212 | | $ | (157) | | $ | 55 | | | $ | 212 | | $ | (150) | | $ | 62 | |
| Trade names | 64 | | (41) | | 23 | | | 64 | | (38) | | 26 | |
| PPA fair value adjustments | 390 | | (119) | | 271 | | | 390 | | (109) | | 281 | |
| Other | 10 | | (9) | | 1 | | | 11 | | (10) | | 1 | |
| Total other intangible assets subject to amortization | $ | 676 | | $ | (326) | | $ | 350 | | | $ | 677 | | $ | (307) | | $ | 370 | |
| Other intangible assets not subject to amortization: | | | | | | | |
| Federal Communications Commission licenses | 75 | | — | | 75 | | | 75 | | — | | 75 | |
| Total other intangible assets | $ | 751 | | $ | (326) | | $ | 425 | | | $ | 752 | | $ | (307) | | $ | 445 | |
| | | | | | | |
| Southern Power | | | | | | | |
| Other intangible assets subject to amortization: | | | | | | | |
| PPA fair value adjustments | $ | 390 | | $ | (119) | | $ | 271 | | | $ | 390 | | $ | (109) | | $ | 281 | |
| | | | | | | |
| Southern Company Gas | | | | | | | |
| Other intangible assets subject to amortization: | | | | | | | |
| Gas marketing services | | | | | | | |
| Customer relationships | $ | 156 | | $ | (135) | | $ | 21 | | | $ | 156 | | $ | (130) | | $ | 26 | |
| Trade names | 26 | | (16) | | 10 | | | 26 | | (15) | | 11 | |
| Total other intangible assets subject to amortization | $ | 182 | | $ | (151) | | $ | 31 | | | $ | 182 | | $ | (145) | | $ | 37 | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Amortization associated with other intangible assets was as follows:
| | | | | | | | |
| Three Months Ended | Six Months Ended |
| June 30, 2022 |
| (in millions) |
Southern Company(a) | $ | 9 | | $ | 19 | |
Southern Power(b) | 5 | | 10 | |
| Southern Company Gas | 2 | | 5 | |
(a)Includes $5 million and $10 million for the three and six months ended June 30, 2022, respectively, recorded as a reduction to operating revenues.
(b)Recorded as a reduction to operating revenues.
Cash, Cash Equivalents, and Restricted Cash
The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amount shown in the condensed statements of cash flows for the applicable Registrants:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Southern
Company | | Southern
Power | | Southern
Company Gas |
| June 30, 2022 | December 31, 2021 | | June 30, 2022 | December 31, 2021 | | June 30, 2022 | December 31, 2021 |
| (in millions) |
| Cash and cash equivalents | $ | 1,724 | | $ | 1,798 | | | $ | 202 | | $ | 107 | | | $ | 217 | | $ | 45 | |
Restricted cash(a): | | | | | | | | |
| Other current assets | 2 | | 2 | | | — | | — | | | 2 | | 2 | |
| Other deferred charges and assets | 9 | | 29 | | | 9 | | 29 | | | — | | — | |
Total cash, cash equivalents, and restricted cash(b) | $ | 1,735 | | $ | 1,829 | | | $ | 211 | | $ | 135 | | | $ | 218 | | $ | 48 | |
(a)For Southern Power, reflects $9 million and $10 million at June 30, 2022 and December 31, 2021, respectively, held to fund estimated construction completion costs at the Deuel Harvest wind facility and $19 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 collateral for workers' compensation, life insurance, and long-term disability insurance.
(b)Total may not add due to rounding.
Natural Gas for Sale
With the exception of Nicor Gas, Southern Company Gas records natural gas inventories on a WACOG basis. For any declines in market prices below the WACOG considered to be other than temporary, an adjustment is recorded to reduce the value of natural gas inventories to market value. Nicor Gas' natural gas inventory is carried at cost on a LIFO basis. Inventory decrements occurring during the year that are restored prior to year end are charged to cost of natural gas at the estimated annual replacement cost. Inventory decrements that are not restored prior to year end are charged to cost of natural gas at the actual LIFO cost of the inventory layers liquidated.
Southern Company Gas recorded no material adjustments to natural gas inventories for either period presented. Nicor Gas' inventory decrement at June 30, 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 30 years to up to 35 years. This revision resulted in an immaterial decrease in depreciation for the three and six months ended June 30, 2022 and is expected to result in an immaterial decrease in annual depreciation for 2022.
(B) REGULATORY MATTERS
See Note 2 to the financial statements in Item 8 of the Form 10-K for additional information relating to regulatory matters.
The recovery balances for certain retail regulatory clauses of the traditional electric operating companies and Southern Company Gas at June 30, 2022 and December 31, 2021 were as follows:
| | | | | | | | | | | |
| Regulatory Clause | Balance Sheet Line Item | June 30,
2022 | December 31, 2021 |
| | (in millions) |
| Alabama Power | | | |
| | | |
| | | |
| Rate CNP Compliance | Other regulatory assets, deferred | $ | 29 | | $ | 16 | |
| | | |
| Rate CNP PPA | Other regulatory assets, deferred | 93 | | 84 | |
| | | |
| | | |
Retail Energy Cost Recovery(*) | Other regulatory assets, current | 60 | | — | |
| Other regulatory assets, deferred | 191 | | 126 | |
| | | |
| | | |
| Georgia Power | | | |
| | | |
| Fuel Cost Recovery | Deferred under recovered fuel clause revenues | $ | 948 | | $ | 410 | |
| | | |
| Mississippi Power | | | |
| | | |
| Fuel Cost Recovery | Other customer accounts receivable | $ | 29 | | $ | 4 | |
| Ad Valorem Tax | Other regulatory assets, current | 12 | | 12 | |
| Other regulatory assets, deferred | 29 | | 37 | |
| | | |
| | | |
| Southern Company Gas | | | |
| | | |
| Natural Gas Cost Recovery | Natural gas cost under recovery | $ | 361 | | $ | 266 | |
| Other regulatory assets, deferred | 15 | | 207 | |
| | | |
(*)In accordance with an Alabama PSC order issued on February 1, 2022, Alabama Power applied $126 million of its 2021 Rate RSE refund to reduce the Rate ECR under recovered balance.
Alabama Power
Certificate of Convenience and Necessity
On July 12, 2022, the Alabama PSC approved and, on July 15, 2022, issued its order regarding Alabama Power's petition for a certificate of convenience and necessity (CCN) which authorizes Alabama Power to complete the acquisition of the Calhoun Generating Station, which was approved by the FERC on March 25, 2022, and is expected to close by September 30, 2022. Alabama Power expects to recover all approved costs associated with the acquisition through existing rate mechanisms as outlined in Note 2 to the financial statements in Item 8 of the Form 10-K. The Alabama PSC's order is subject to any rehearing request or judicial appeal filed on or before August 15, 2022. The ultimate outcome of this matter cannot be determined at this time.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Rate ECR
On July 12, 2022, the Alabama PSC approved an adjustment to Rate ECR from 1.960 cents per KWH to 2.557 cents per KWH, or approximately $310 million annually, effective with August 2022 billings. The approved increase in the Rate ECR factor will have no significant effect on Alabama Power's net income, but will increase operating cash flows related to fuel cost recovery. The rate will adjust to 5.910 cents per KWH in January 2025 absent a further order from the Alabama PSC.
Rate NDR
On July 12, 2022, the Alabama PSC approved modifications to Rate NDR, which include an adjustment to the charges to establish and maintain the reserve and an adjustment to the recovery period for any existing deferred storm-related operations and maintenance costs and future reserve deficits from 24 months to 48 months. As modified, the maximum total Rate NDR charge to recover a deficit is limited to $5.00 per month per non-residential customer account and $2.50 per month per residential customer account.
At June 30, 2022, Alabama Power's NDR balance was $103 million. Beginning with August 2022 billings, the reserve establishment charge will be suspended and the reserve maintenance charge will be activated as a result of the NDR balance exceeding $75 million. Alabama Power expects to collect $6 million in the second half of 2022 and approximately $12 million annually beginning in 2023 under Rate NDR unless the NDR balance falls below $50 million. Alabama Power continues to have the authority to accrue additional amounts to the NDR as circumstances warrant.
Reliability Reserve Accounting Order
On July 12, 2022, the Alabama PSC approved an accounting order authorizing Alabama Power to create a reliability reserve separate from the NDR and transition the previous Rate NDR authority related to reliability expenditures to the reliability reserve. Alabama Power may make accruals to the reliability reserve if the NDR balance exceeds $35 million.
Renewable Generation Certificate
Through the issuance of a Renewable Generation Certificate (RGC), Alabama Power is authorized by the Alabama PSC to procure up to 500 MWs of renewable capacity and energy by September 16, 2027 and to market the related energy and environmental attributes to customers and other third parties. In April 2022, one of the existing solar projects which was expected to be served through a PPA commencing in first quarter 2024 was terminated, resulting in the restoration of 80 MWs of capacity under the RGC. The ultimate outcome of this matter cannot be determined at this time.
Georgia Power
Rate Plans
2022 Base Rate Case
On June 24, 2022, Georgia Power filed a base rate case (Georgia Power 2022 Base Rate Case) with the Georgia PSC. The filing proposes continuation of a three-year alternate rate plan with requested rate increases totaling $852 million, $107 million, and $45 million effective January 1, 2023, January 1, 2024, and January 1, 2025, respectively. These increases are based on a proposed retail ROE of 11.00% using the currently approved equity ratio of 56% and reflect levelized revenue requirements during the three-year period, with the exception of incremental compliance costs related to CCR AROs, Demand-Side Management (DSM) programs, and related adjustments to the Municipal Franchise Fee tariff.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Georgia Power has requested recovery of the proposed increases through its existing base rate tariffs as follows:
| | | | | | | | | | | | | | | | | |
| Tariff | 2023 | | 2024 | | 2025 |
| (in millions) |
| Traditional base | $ | 739 | | | $ | — | | | $ | — | |
| ECCR | | | | | |
| Traditional | (1) | | | — | | | — | |
CCR ARO(a) | 64 | | | 78 | | | 47 | |
DSM(a) | 30 | | | 27 | | | (2) | |
| Municipal Franchise Fee | 20 | | | 2 | | | 1 | |
Total(b) | $ | 852 | | | $ | 107 | | | $ | 45 | |
(a)As determined by the Georgia PSC through annual compliance filings.
(b)Totals may not add due to rounding.
Georgia Power's filing primarily reflects requests to (i) recover the costs of recent and future capital investments in the electric grid including the transmission and distribution systems and the continuation of its grid investment plan, all designed to support customer long-term reliability and resiliency needs, (ii) recover the cost of coal-fired generation units proposed for retirement, or made unavailable, as requested in the 2022 IRP, as Georgia Power continues the transition of the generation fleet to more economical and cleaner resources, (iii) make the necessary investments and recover costs to comply with federal and state environmental regulations, including costs associated with the CCR AROs related to ash pond and landfill closures and post-closure care, and (iv) reduce operating costs despite significant inflationary pressures. In addition, the filing includes the following provisions:
•Continuation of an allowed retail ROE range of 9.50% to 12.00%.
•Continuation of the process whereby 80% of any earnings above the top of the allowed ROE range are shared with Georgia Power's customers and the remaining 20% are retained by Georgia Power.
•Continuation of the option to file an Interim Cost Recovery tariff in the event earnings are projected to fall below the bottom of the allowed ROE range during the three-year term of the plan.
Georgia Power expects the Georgia PSC to render a final decision in this matter on December 20, 2022. The ultimate outcome of this matter cannot be determined at this time.
2019 ARP
In 2020, the Georgia PSC denied a motion for reconsideration filed by 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, Sierra Club filed a petition for writ of certiorari to the Georgia Supreme Court, which was denied on July 14, 2022. This matter is now concluded. 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 Plans
In response to supply chain challenges in the solar industry, the Georgia PSC approved Georgia Power's request to amend 970 MWs of utility-scale solar PPAs that were authorized by the Georgia PSC in Georgia Power's 2019 IRP. The amendments extended the required commercial operation dates for the PPAs from 2023 to 2024.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
On July 21, 2022, the Georgia PSC approved the 2022 IRP, as modified by a stipulated agreement among Georgia Power, the staff of the Georgia PSC, and certain intervenors and as further modified by the Georgia PSC. In the 2022 IRP decision, the Georgia PSC approved the following requests:
•Decertification and retirement of Plant Wansley Units 1 and 2 (926 MWs based on 53.5% ownership) by August 31, 2022 and reclassification to regulatory asset accounts of the remaining net book values ($302 million and $279 million for Unit 1 and Unit 2, respectively, at June 30, 2022) and any remaining unusable materials and supplies inventories upon retirement. The regulatory asset accounts for the net book values of the units will be amortized at a rate equal to the unit depreciation rates authorized in the 2019 ARP through December 31, 2022. In the Georgia Power 2022 Base Rate Case, Georgia Power requested recovery of the remaining regulatory asset balances for the net book values of the units through 2030 and requested that the timing of recovery of the regulatory asset account for the unusable materials and supplies inventories be determined in a future base rate case.
•Decertification and retirement of Plant Scherer Unit 3 (614 MWs based on 75% ownership) by December 31, 2028 and reclassification to regulatory asset accounts of the remaining net book value (approximately $614 million at June 30, 2022) and any remaining unusable materials and supplies inventory to regulatory asset accounts upon retirement. The timing of recovery for these regulatory assets is expected to be determined in a future base rate case.
•Decertification and retirement of Plant Gaston Units 1 through 4 (500 MWs based on 50% ownership through SEGCO) by December 31, 2028. See Note 7 to the financial statements under "SEGCO" in Item 8 of the Form 10-K for additional information.
•Georgia Power's environmental compliance strategy, including approval of Georgia Power's plans to address CCR at its ash ponds and landfills. Recovery of the related costs is expected to be determined in future base rate cases. The Georgia PSC's approval included a change in the method of closure for one ash pond. Georgia Power is currently evaluating the related impact on its cost estimates and AROs; however, it is not expected to be material.
•Installation of environmental controls at Plants Bowen and Scherer for compliance with rules related to effluent limitations guidelines.
•Initiation of a license renewal application with the NRC for Plant Hatch.
•Investments related to the continued hydro operations of Plants Sinclair and Burton.
•Provisional authorization for development of a 265-MW battery energy storage facility with expected commercial operation in 2026.
•Issuance of requests for proposals (RFP) for 2,300 MWs of renewable resources, an additional 500 MWs of energy storage, and up to 140 MWs of biomass generation.
•Related transmission projects necessary to support the generation facilities plan.
•Certification of six PPAs (including five affiliate PPAs with Southern Power that are subject to approval by the FERC) with capacities of 1,567 MWs beginning in 2024, 380 MWs beginning in 2025, and 228 MWs beginning in 2028, procured through RFPs authorized in the 2019 IRP. See Note (F) under "Georgia Power Lease Modification" for additional information.
The Georgia PSC deferred a decision on the requested decertification and retirement of Plant Bowen Units 1 and 2 (1,400 MWs) to the 2025 IRP and rejected Georgia Power's request to certify approximately 88 MWs of wholesale capacity to be placed in retail rate base between January 1, 2024 and January 1, 2025. Georgia Power may offer such capacity in the wholesale market or to the retail jurisdiction in a future regulatory proceeding.
The ultimate outcome of these matters cannot be determined at this time.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Nuclear Construction
In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4, in which Georgia Power holds a 45.7% ownership interest. In 2012, the NRC issued the related combined construction and operating licenses, which allowed full construction of the two AP1000 nuclear units (with electric generating capacity of approximately 1,100 MWs each) and related facilities to begin. Until March 2017, construction on Plant Vogtle Units 3 and 4 continued under the Vogtle 3 and 4 Agreement, which was a substantially fixed price agreement.
In connection with the EPC Contractor's bankruptcy filing in March 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into several transitional arrangements to allow construction to continue. In July 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into the Vogtle Services Agreement, whereby Westinghouse provides facility design and engineering services, procurement and technical support, and staff augmentation on a time and materials cost basis. The Vogtle Services Agreement provides that it will continue until the start-up and testing of Plant Vogtle Units 3 and 4 are complete and electricity is generated and sold from both units. The Vogtle Services Agreement is terminable by the Vogtle Owners upon 30 days' written notice.
In October 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, executed the Bechtel Agreement, under which Bechtel is reimbursed for actual costs plus a base fee and an at-risk fee, subject to adjustment based on Bechtel's performance against cost and schedule targets. Each Vogtle Owner is severally (not jointly) liable for its proportionate share, based on its ownership interest, of all amounts owed to Bechtel under the Bechtel Agreement. The Vogtle Owners may terminate the Bechtel Agreement at any time for their convenience, provided that the Vogtle Owners will be required to pay amounts related to work performed prior to the termination (including the applicable portion of the base fee), certain termination-related costs, and, at certain stages of the work, the applicable portion of the at-risk fee. Bechtel may terminate the Bechtel Agreement under certain circumstances, including certain Vogtle Owner suspensions of work, certain breaches of the Bechtel Agreement by the Vogtle Owners, Vogtle Owner insolvency, and certain other events.
See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K for information on the Amended and Restated Loan Guarantee Agreement, including applicable covenants, events of default, and mandatory prepayment events.
Cost and Schedule
Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4, including contingency, through the end of the first quarter 2023 and the fourth quarter 2023, respectively, is as follows:
| | | | | |
| (in millions) |
Base project capital cost forecast(a)(b) | $ | 10,393 | |
| Construction contingency estimate | 60 | |
| |
Total project capital cost forecast(a)(b) | 10,453 | |
Net investment at June 30, 2022(b) | (8,966) | |
| Remaining estimate to complete | $ | 1,487 | |
(a)Includes approximately $590 million of costs that are not shared with the other Vogtle Owners and approximately $455 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 $385 million, of which $247 million had been accrued through June 30, 2022.
(b)Net of $1.7 billion received from Toshiba under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds.
Georgia Power estimates that its financing costs for construction of Plant Vogtle Units 3 and 4 will total approximately $3.4 billion, of which $3.0 billion had been incurred through June 30, 2022.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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 four months of schedule margin previously embedded in the site work plan for Unit 3 and Unit 4. As of June 30, 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 $160 million and $200 million and is included in the total project capital cost forecast. The continuing effects of the COVID-19 pandemic could further disrupt or delay construction and testing activities at Plant Vogtle Units 3 and 4.
Fuel load for Unit 3 is projected during the fourth quarter 2022 with an in-service date projected during the first quarter 2023. Unit 3's projected schedule primarily depends on 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 fourth quarter 2023 for Unit 4 is projected. Unit 4's projected schedule primarily depends on Unit 3 progress through fuel load, startup, and testing; overall construction productivity and production levels improving, particularly in electrical installation, including terminations; and appropriate levels of craft laborers, particularly electricians and pipefitters, being added and maintained. Any further delays could result in later in-service dates and cost increases.
During the first half of 2022, established construction contingency totaling $126 million was assigned to the base capital cost forecast for costs primarily associated with construction productivity, the pace of system turnovers, additional craft and support resources, and procurement for Units 3 and 4. Georgia Power also increased its total project capital cost forecast as of June 30, 2022 by adding $36 million to replenish construction contingency. After considering the significant level of uncertainty that exists regarding the future recoverability of these costs since the ultimate outcome of these matters is subject to the outcome of future assessments by management, as well as Georgia PSC decisions in future regulatory proceedings, Georgia Power recorded a pre-tax charge to income in the second quarter 2022 of $36 million ($27 million after tax) for the increase in the total project capital cost forecast. Georgia Power may request the Georgia PSC to evaluate those expenditures for rate recovery during the prudence review following the Unit 4 fuel load pursuant to the twenty-fourth VCM stipulation described below.
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, 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.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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. Additional license amendment requests also may be filed with 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 $35 million per month for Unit 3 and $45 million per month for Unit 4, as well as the related AFUDC and any additional related construction, support resources, or testing costs. While Georgia Power is not precluded from seeking retail recovery of any future capital cost forecast increase other than the amounts related to the cost-sharing and tender provisions of the joint ownership agreements described below, management will ultimately determine whether or not to seek recovery. Any further changes to the capital cost forecast that are not expected to be recoverable through regulated rates will be required to be charged to income and such charges could be material.
Joint Owner Contracts
In November 2017, the Vogtle Owners entered into an amendment to their joint ownership agreements for Plant Vogtle Units 3 and 4 to provide for, among other conditions, additional Vogtle Owner approval requirements. Effective in August 2018, the Vogtle Owners further amended the joint ownership agreements to clarify and provide procedures for certain provisions of the joint ownership agreements related to adverse events that require the vote of the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 to continue construction (as amended, and together with the November 2017 amendment, the Vogtle Joint Ownership Agreements). The Vogtle Joint Ownership Agreements also confirm that the Vogtle Owners' sole recourse against Georgia Power or Southern Nuclear for any action or inaction in connection with their performance as agent for the Vogtle Owners is limited to removal of Georgia Power and/or Southern Nuclear as agent, except in cases of willful misconduct.
Amendments to the Vogtle Joint Ownership Agreements
In connection with a September 2018 vote by the Vogtle Owners to continue construction, Georgia Power entered into (i) a binding term sheet (Vogtle Owner Term Sheet) with the other Vogtle Owners and MEAG Power's wholly-owned subsidiaries MEAG Power SPVJ, LLC (MEAG SPVJ), MEAG Power SPVM, LLC (MEAG SPVM), and MEAG Power SPVP, LLC (MEAG SPVP) to take certain actions which partially mitigate potential financial exposure for the other Vogtle Owners, including additional amendments to the Vogtle Joint Ownership Agreements and the purchase of PTCs from the other Vogtle Owners at pre-established prices, and (ii) a term sheet (MEAG Term Sheet) with MEAG Power and MEAG SPVJ to provide up to $300 million of funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle Units 3 and 4 under certain circumstances. In January 2019, Georgia Power, MEAG Power, and MEAG SPVJ entered into an agreement to implement the provisions of the MEAG Term Sheet. In February 2019, Georgia Power, the other Vogtle Owners, and MEAG Power's wholly-owned subsidiaries
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
MEAG SPVJ, MEAG SPVM, and MEAG SPVP entered into certain amendments to the Vogtle Joint Ownership Agreements to implement the provisions of the Vogtle Owner Term Sheet (Global Amendments).
Pursuant to the Global Amendments: (i) each Vogtle Owner must pay its proportionate share of qualifying construction costs for Plant Vogtle Units 3 and 4 based on its ownership percentage up to the estimated cost at completion (EAC) for Plant Vogtle Units 3 and 4 which formed the basis of Georgia Power's forecast of $8.4 billion in the nineteenth VCM plus $800 million; (ii) Georgia Power will be responsible for 55.7% of actual qualifying construction costs between $800 million and $1.6 billion over the EAC in the nineteenth VCM (resulting in $80 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 44.3% of such costs pro rata in accordance with their respective ownership interests; and (iii) Georgia Power will be responsible for 65.7% of qualifying construction costs between $1.6 billion and $2.1 billion over the EAC in the nineteenth VCM (resulting in a further $100 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 34.3% of such costs pro rata in accordance with their respective ownership interests. If the EAC is revised and exceeds the EAC in the nineteenth VCM by more than $2.1 billion, each of the other Vogtle Owners will have a one-time option at the time the project budget cost forecast is so revised to tender a portion of its ownership interest to Georgia Power in exchange for Georgia Power's agreement to pay 100% of such Vogtle Owner's remaining share of total construction costs in excess of the EAC in the nineteenth VCM plus $2.1 billion.
For purposes of the foregoing provisions, qualifying construction costs will not include costs (i) resulting from force majeure events, including epidemics and quarantines, governmental actions or inactions (or significant delays associated with issuance of such actions) that affect the licensing, completion, start-up, operations, or financing of Plant Vogtle Units 3 and 4, administrative proceedings or litigation regarding ITAAC or other regulatory challenges to commencement of operation of Plant Vogtle Units 3 and 4, and changes in laws or regulations governing Plant Vogtle Units 3 and 4, (ii) legal fees and legal expenses incurred due to litigation with contractors or subcontractors that are not subsidiaries or affiliates of Southern Company, and (iii) additional costs caused by requests from the Vogtle Owners other than Georgia Power, except for the exercise of a right to vote granted under the Vogtle Joint Ownership Agreements, that increase costs by $100,000 or more.
In addition, pursuant to the Global Amendments, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 must vote to continue construction if certain adverse events occur, including, among other events: (i) the bankruptcy of Toshiba; (ii) the termination or rejection in bankruptcy of certain agreements, including the Vogtle Services Agreement, the Bechtel Agreement, or the agency agreement with Southern Nuclear; (iii) Georgia Power's public announcement of its intention not to submit for rate recovery any portion of its investment in Plant Vogtle Units 3 and 4 or the Georgia PSC determines that any of Georgia Power's costs relating to the construction of Plant Vogtle Units 3 and 4 will not be recovered in retail rates, excluding any additional amounts paid by Georgia Power on behalf of the other Vogtle Owners pursuant to the Global Amendments described above and the first 6% of costs during any six-month VCM reporting period that are disallowed by the Georgia PSC for recovery, or for which Georgia Power elects not to seek cost recovery, through retail rates; and (iv) an incremental extension of one year or more from the seventeenth VCM report estimated in-service dates of November 2021 and November 2022 for Units 3 and 4, respectively. The schedule extension announced in February 2022 triggered the requirement for a vote to continue construction. 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 $18.38 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 pre-tax charges to income in the fourth quarter 2021 and the second quarter 2022 of approximately $440 million ($328 million after tax) and $16 million ($12 million after tax), respectively, associated with these cost-sharing and tender provisions, which are
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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 $480 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, which was modified on June 3, 2022, to clarify the process for the tender provisions of the Global Amendments to provide for a decision between 120 and 194 days after the tender option is triggered, which the other Vogtle Owners assert occurred on February 14, 2022, and would require the other Vogtle Owners to notify Georgia Power of their intent to exercise their tender options by August 27, 2022. On June 17, 2022 and July 26, 2022, OPC and Dalton, respectively, notified Georgia Power of their purported exercises of their tender options. On June 18, 2022, OPC and MEAG Power each filed a separate lawsuit against Georgia Power in the Superior Court of Fulton County, Georgia seeking a declaratory judgment that the starting dollar amount is $17.1 billion and that the cost-sharing and tender provisions have been triggered. The lawsuits also assert other claims, including breach of contract allegations, and seek, among other remedies, damages and injunctive relief requiring Georgia Power to track and allocate construction costs consistent with MEAG Power's and OPC's interpretations of the Global Amendments. On July 25, 2022, Georgia Power filed its answer in the lawsuit filed by MEAG Power and included counterclaims seeking a declaratory judgment that the starting dollar amount is $18.38 billion and that costs related to force majeure events are excluded prior to calculating the cost-sharing and tender provisions and when calculating Georgia Power's related financial obligations.
Georgia Power's ownership interest in Plant Vogtle Units 3 and 4 continues to be 45.7%; however, it could increase if one or more of the other Vogtle Owners effectively exercise the option to tender a portion of their ownership interest to Georgia Power and require Georgia Power to pay 100% of the remaining share of the costs necessary to complete Plant Vogtle Units 3 and 4. Georgia Power's incremental ownership interest would be calculated and conveyed to Georgia Power after Plant Vogtle Units 3 and 4 are placed in service.
The ultimate outcome of these matters cannot be determined at this time.
Regulatory Matters
In 2009, the Georgia PSC voted to certify construction of Plant Vogtle Units 3 and 4 with a certified capital cost of $4.418 billion. In addition, in 2009 the Georgia PSC approved inclusion of the Plant Vogtle Units 3 and 4 related CWIP accounts in rate base, and the State of Georgia enacted the Georgia Nuclear Energy Financing Act, which allows Georgia Power to recover financing costs for Plant Vogtle Units 3 and 4. Financing costs are recovered on all applicable certified costs through annual adjustments to the NCCR tariff up to the certified capital cost of $4.418 billion. At June 30, 2022, Georgia Power had recovered approximately $2.8 billion of financing costs. Financing costs related to capital costs above $4.418 billion are being recognized through AFUDC and are expected to be recovered through retail rates over the life of Plant Vogtle Units 3 and 4; however, Georgia Power is not recording AFUDC related to any capital costs in excess of the total deemed reasonable by the Georgia PSC (currently $7.3 billion) and not requested for rate recovery. In November 2021, the Georgia PSC approved Georgia Power's request to decrease the NCCR tariff by $78 million annually, effective January 1, 2022.
Georgia Power is required to file semi-annual VCM reports with the Georgia PSC by February 28 and August 31 of each year. In 2013, in connection with the eighth VCM report, the Georgia PSC approved a stipulation between Georgia Power and the staff of the Georgia PSC to waive the requirement to amend the Plant Vogtle Units 3 and 4 certificate in accordance with the 2009 certification order until the completion of Plant Vogtle Unit 3, or earlier if deemed appropriate by the Georgia PSC and Georgia Power.
In 2016, the Georgia PSC voted to approve a settlement agreement (Vogtle Cost Settlement Agreement) resolving certain prudency matters in connection with the fifteenth VCM report. In December 2017, the Georgia PSC voted to approve (and issued its related order on January 11, 2018) Georgia Power's seventeenth VCM report and modified the Vogtle Cost Settlement Agreement. The Vogtle Cost Settlement Agreement, as modified by the January 11, 2018 order, resolved the following regulatory matters related to Plant Vogtle Units 3 and 4: (i) none of the $3.3 billion of costs incurred through December 31, 2015 and reflected in the fourteenth VCM report should be disallowed from rate base on the basis of imprudence; (ii) the Contractor Settlement Agreement was reasonable and
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
prudent and none of the $0.3 billion paid pursuant to the Contractor Settlement Agreement should be disallowed from rate base on the basis of imprudence; (iii) (a) capital costs incurred up to $5.68 billion would be presumed to be reasonable and prudent with the burden of proof on any party challenging such costs, (b) Georgia Power would have the burden to show that any capital costs above $5.68 billion were prudent, and (c) a revised capital cost forecast of $7.3 billion (after reflecting the impact of payments received under the Guarantee Settlement Agreement and related customer refunds) was found reasonable; (iv) construction of Plant Vogtle Units 3 and 4 should be completed, with Southern Nuclear serving as project manager and Bechtel as primary contractor; (v) approved and deemed reasonable Georgia Power's revised schedule placing Plant Vogtle Units 3 and 4 in service in November 2021 and November 2022, respectively; (vi) confirmed that the revised cost forecast does not represent a cost cap and that a prudence proceeding on cost recovery will occur following Unit 4 fuel load, consistent with applicable Georgia law; (vii) reduced the ROE used to calculate the NCCR tariff (a) from 10.95% (the ROE rate setting point authorized by the Georgia PSC in the 2013 alternate rate plan) to 10.00% effective January 1, 2016, (b) from 10.00% to 8.30%, effective January 1, 2020, and (c) from 8.30% to 5.30%, effective January 1, 2021 (provided that the ROE in no case will be less than Georgia Power's average cost of long-term debt); (viii) reduced the ROE used for AFUDC equity for Plant Vogtle Units 3 and 4 from 10.00% to Georgia Power's average cost of long-term debt, effective January 1, 2018; and (ix) agreed that effective the first month after Unit 3 reaches commercial operation, retail base rates would be adjusted to include the costs related to Unit 3 and common facilities deemed prudent in the Vogtle Cost Settlement Agreement (see Note 2 to the financial statements under "Georgia Power – Plant Vogtle Unit 3 and Common Facilities Rate Proceeding" in Item 8 of the Form 10-K for additional information). The January 11, 2018 order also stated that if Plant Vogtle Units 3 and 4 are not commercially operational by June 1, 2021 and June 1, 2022, respectively, the ROE used to calculate the NCCR tariff will be further reduced by 10 basis points each month (but not lower than Georgia Power's average cost of long-term debt) until the respective Unit is commercially operational. The ROE reductions negatively impacted earnings by approximately $270 million in 2021 and are estimated to have negative earnings impacts of approximately $300 million and $250 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 $7.3 billion determined to be reasonable in the Georgia PSC's seventeenth VCM order and (ii) Georgia Power will not seek rate recovery of the $0.7 billion increase to the base capital cost forecast included in the nineteenth VCM report and charged to income by Georgia Power in the second quarter 2018. In addition, the stipulation confirms Georgia Power may request verification and approval of costs above $7.3 billion for inclusion in rate base at a later time, but no earlier than the prudence review contemplated by the seventeenth VCM order described previously.
The Georgia PSC has approved 25 VCM reports covering periods through June 30, 2021. These reports reflect total construction capital costs incurred of $7.9 billion (net of $1.7 billion of payments received under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds), of which the Georgia PSC has verified and approved $7.3 billion as described above. The Georgia PSC has reviewed the twenty-sixth VCM report, which reflects $584 million of additional construction capital costs incurred through December 31, 2021. Georgia Power expects to file its twenty-seventh VCM report with the Georgia PSC by August 31, 2022, which will reflect the revised capital cost forecast discussed above and $522 million of construction capital costs incurred from January 1, 2022 through June 30, 2022.
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 June 7, 2022, the Mississippi PSC approved Mississippi Power's annual retail PEP filing for 2022, resulting in an annual increase in revenues of approximately $18 million, or 1.9%, primarily due to increases in rate base, operations and maintenance expenses, and depreciation and amortization. The rate increase became effective with the first billing cycle of April 2022 in accordance with the PEP rate schedule.
Ad Valorem Tax Adjustment
On June 7, 2022, the Mississippi PSC approved Mississippi Power's annual ad valorem tax adjustment filing for 2022, resulting in an annual increase in revenues of $5 million, effective with the first billing cycle of July 2022.
Municipal and Rural Associations Tariff
On May 26, 2022, Mississippi Power and Cooperative Energy executed an amended shared service agreement (SSA) under which Cooperative Energy will continue to decrease its use of Mississippi Power's generation services under the MRA tariff up to 2.5% annually through 2035. At June 30, 2022, Mississippi Power is serving approximately 400 MWs of Cooperative Energy's annual demand. Beginning in 2036, Cooperative Energy will provide 100% of its electricity requirements at the MRA delivery points under the tariff. Neither party has the option to cancel the amended SSA. On June 30, 2022, Mississippi Power filed a request with the FERC for approval of the amended SSA.
On July 15, 2022, Mississippi Power filed a request with the FERC for a $23 million increase in annual wholesale base revenues under the MRA tariff and requested an effective date of July 15, 2022.
The ultimate outcome of these matters cannot be determined at this time.
Southern Company Gas
Infrastructure Replacement Programs and Capital Projects
Capital expenditures incurred under specific infrastructure replacement programs and capital projects during the first six months of 2022 were as follows:
| | | | | | | | |
| Utility | Program | Six Months Ended June 30, 2022 |
| | (in millions) |
| Nicor Gas | Investing in Illinois | $ | 177 | |
| Virginia Natural Gas | Steps to Advance Virginia's Energy | 33 | |
| Atlanta Gas Light | System Reinforcement Rider | 28 | |
| Chattanooga Gas | Pipeline Replacement Program | 2 | |
| Total | | $ | 240 | |
Rate Proceedings
Atlanta Gas Light
On July 1, 2022, Atlanta Gas Light filed its annual GRAM update with the Georgia PSC. The filing requests an annual base rate increase of $53 million based on the projected 12-month period beginning January 1, 2023. Resolution of the GRAM filing is expected by December 28, 2022, with the new rates effective January 1, 2023. The ultimate outcome of this matter cannot be determined at this time.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Virginia Natural Gas
On May 31, 2022, Virginia Natural Gas filed a notice of intent with the Virginia State Corporation Commission to file a base rate case later in the third quarter 2022. The ultimate outcome of this matter cannot be determined at this time.
(C) CONTINGENCIES
See Note 3 to the financial statements in Item 8 of the Form 10-K for information relating to various lawsuits and other contingencies.
General Litigation Matters
The Registrants are involved in various matters being litigated and regulatory matters. The ultimate outcome of such pending or potential litigation or regulatory matters against each Registrant and any subsidiaries cannot be determined at this time; however, for current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, arising from such current proceedings would have a material effect on such Registrant's financial statements.
The Registrants believe the pending legal challenges discussed below have no merit; however, the ultimate outcome of these matters cannot be determined at this time.
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 named as defendants Southern Company, certain of its directors, certain of its current and former officers, and certain former Mississippi Power officers. In 2017, these two shareholder derivative lawsuits were consolidated in the U.S. District Court for the Northern District of Georgia. The complaints alleged that the defendants caused Southern Company to make false or misleading statements regarding the Kemper County energy facility cost and schedule. Further, the complaints alleged that the defendants were unjustly enriched and caused the waste of corporate assets and also alleged 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 named as defendants Southern Company, certain of its directors, certain of its current and former officers, and certain former Mississippi Power officers. The complaint alleged 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 alleged 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 sought 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 sought 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 applied to both actions. On June 9, 2022, the U.S. District Court for the Northern District of Georgia granted final approval of the settlement and, on June 16, 2022, the Superior Court of Gwinnett County, Georgia entered an order awarding attorneys' fees and expenses related to the Martin J. Kobuck lawsuit. The settlement consists of an aggregate payment by Southern Company's insurers of approximately $4.5 million for attorneys' fees and expenses, as well as adoption of various corporate governance reforms by Southern Company. These matters are now concluded.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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, three additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power alleging that releases from Plant Scherer have impacted groundwater and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages. In November 2021, Georgia Power filed a notice to remove the three 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, four additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power seeking damages for alleged personal injuries or property damage. On March 9, 2022, Georgia Power filed a notice to remove the four cases pending in the Superior Court of Monroe 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 10 other individual plaintiffs filed a putative class action complaint against Mississippi Power and the three then-serving members of the Mississippi PSC in the U.S. District Court for the Southern District of Mississippi, which was amended in March 2019 to include four additional plaintiffs. Mississippi Power received Mississippi PSC approval in 2013 to charge a mirror CWIP rate premised upon including in its rate base pre-construction and construction costs for the Kemper IGCC prior to placing the Kemper IGCC into service. The Mississippi Supreme Court reversed that approval and ordered Mississippi Power to refund the amounts paid by customers under the previously-approved mirror CWIP rate. The plaintiffs allege that the initial approval process, and the amount approved, were improper and make claims for gross negligence, reckless conduct, and intentional wrongdoing. They also allege that Mississippi Power underpaid customers by up to $23.5 million in the refund process by applying an incorrect interest rate. The plaintiffs seek to recover, on behalf of themselves and their putative class, actual damages, punitive damages, pre-judgment interest, post-judgment interest, attorney's fees, and costs. The district court dismissed the amended complaint; however, in March 2020, the plaintiffs filed a motion seeking to name the new members of the Mississippi PSC, the Mississippi Development Authority, and Southern Company as additional defendants and add a cause of action against all defendants based on a dormant commerce clause theory under the U.S. Constitution. In July 2020, the plaintiffs filed a motion for leave to file a third amended complaint, which included the same federal claims as the proposed second amended complaint, as well as several additional state law claims based on the allegation that Mississippi Power failed to disclose the annual percentage rate of interest applicable to refunds. In November 2020, the district court denied each of the plaintiffs' pending motions and entered final judgment in favor of Mississippi Power. In January 2021, the district court denied further motions by the plaintiffs to vacate the judgment and to file a revised second amended complaint. In February 2021, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit. On March 21, 2022, the
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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. On May 31, 2022, the U.S. Court of Appeals for the Fifth Circuit denied a petition by Mississippi Power for a rehearing en banc and the case was remanded back to the trial court for further proceedings. On June 17, 2022, Mississippi Power filed with the trial court a motion to dismiss the complaint. 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 $16 million and $17 million at June 30, 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 $241 million and $249 million at June 30, 2022 and December 31, 2021, respectively, based on the estimated cost of environmental investigation and remediation associated with known former manufactured gas plant operating sites.
The ultimate outcome of these matters cannot be determined at this time; however, as a result of the regulatory treatment for environmental remediation expenses described above, the final disposition of these matters is not expected to have a material impact on the financial statements of the applicable Registrants.
Other Matters
Mississippi Power
In conjunction with Southern Company's 2019 sale of Gulf Power, NextEra Energy, Inc. held back $75 million of the purchase price pending Mississippi Power and Gulf Power negotiating a mutually acceptable revised operating agreement for Plant Daniel. On July 12, 2022, the co-owners executed a revised operating agreement and Southern Company subsequently received the remaining $75 million of the purchase price. The revised operating agreement contains dispatch procedures for the two jointly-owned coal units at Plant Daniel such that Mississippi Power will designate one of the two units as primary and the other as secondary in lieu of each company separately owning 100% of a single generating unit. Mississippi Power has the option to purchase its co-owner's ownership interest for $1 on January 15, 2024, provided that Mississippi Power exercises the option no later than 120 days prior to that date. The revised operating agreement is not expected to have a material impact on Mississippi Power's financial statements. See Note 15 to the financial statements under "Southern Company" in Item 8 of the Form 10-K for additional information regarding the sale of Gulf Power.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
(D) REVENUE FROM CONTRACTS WITH CUSTOMERS AND LEASE INCOME
Revenue from Contracts with Customers
The Registrants generate revenues from a variety of sources, some of which are not accounted for as revenue from contracts with customers, such as leases, derivatives, and certain cost recovery mechanisms. See Note 1 to the financial statements under "Revenues" in Item 8 of the Form 10-K for additional information on the revenue policies of the Registrants. See "Lease Income" herein and Note (J) for additional information on revenue accounted for under lease and derivative accounting guidance, respectively.
The following table disaggregates revenue from contracts with customers for the three and six months ended June 30, 2022 and 2021:
| | | | | | | | | | | | | | | | | | | | |
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas |
| (in millions) |
| Three Months Ended June 30, 2022 | | | | | | |
| Operating revenues | | | | | | |
| Retail electric revenues | | | | | | |
| Residential | $ | 1,655 | | $ | 617 | | $ | 962 | | $ | 76 | | $ | — | | $ | — | |
| Commercial | 1,387 | | 410 | | 900 | | 77 | | — | | — | |
| Industrial | 1,005 | | 368 | | 553 | | 84 | | — | | — | |
| Other | 25 | | 3 | | 20 | | 2 | | — | | — | |
| Total retail electric revenues | 4,072 | | 1,398 | | 2,435 | | 239 | | — | | — | |
| Natural gas distribution revenues | | | | | | |
| Residential | 474 | | — | | — | | — | | — | | 474 | |
| Commercial | 130 | | — | | — | | — | | — | | 130 | |
| Transportation | 276 | | — | | — | | — | | — | | 276 | |
| Industrial | 16 | | — | | — | | — | | — | | 16 | |
| Other | 67 | | — | | — | | — | | — | | 67 | |
| Total natural gas distribution revenues | 963 | | — | | — | | — | | — | | 963 | |
| Wholesale electric revenues | | | | | | |
| PPA energy revenues | 585 | | 108 | | 40 | | 5 | | 441 | | — | |
| PPA capacity revenues | 136 | | 40 | | 12 | | — | | 85 | | — | |
| Non-PPA revenues | 62 | | 35 | | 6 | | 169 | | 196 | | — | |
| Total wholesale electric revenues | 783 | | 183 | | 58 | | 174 | | 722 | | — | |
| Other natural gas revenues | | | | | | |
| | | | | | |
| | | | | | |
| Gas marketing services | 90 | | — | | — | | — | | — | | 90 | |
| Other natural gas revenues | 10 | | — | | — | | — | | — | | 10 | |
| Total natural gas revenues | 100 | | — | | — | | — | | — | | 100 | |
| Other revenues | 308 | | 63 | | 121 | | 9 | | 9 | | — | |
| Total revenue from contracts with customers | 6,226 | | 1,644 | | 2,614 | | 422 | | 731 | | 1,063 | |
Other revenue sources(a) | 980 | | 287 | | 507 | | 12 | | 168 | | 20 | |
| | | | | | |
| Total operating revenues | $ | 7,206 | | $ | 1,931 | | $ | 3,121 | | $ | 434 | | $ | 899 | | $ | 1,083 | |
| | | | | | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | | | | | | | |
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas |
| (in millions) |
| Six Months Ended June 30, 2022 | | | | | | |
| Operating revenues | | | | | | |
| Retail electric revenues | | | | | | |
| Residential | $ | 3,179 | | $ | 1,250 | | $ | 1,783 | | $ | 146 | | $ | — | | $ | — | |
| Commercial | 2,567 | | 786 | | 1,638 | | 143 | | — | | — | |
| Industrial | 1,732 | | 691 | | 887 | | 154 | | — | | — | |
| Other | 51 | | 7 | | 40 | | 4 | | — | | — | |
| Total retail electric revenues | 7,529 | | 2,734 | | 4,348 | | 447 | | — | | — | |
| Natural gas distribution revenues | | | | | | |
| Residential | 1,490 | | — | | — | | — | | — | | 1,490 | |
| Commercial | 400 | | — | | — | | — | | — | | 400 | |
| Transportation | 613 | | — | | — | | — | | — | | 613 | |
| Industrial | 48 | | — | | — | | — | | — | | 48 | |
| Other | 195 | | — | | — | | — | | — | | 195 | |
| Total natural gas distribution revenues | 2,746 | | — | | — | | — | | — | | 2,746 | |
| Wholesale electric revenues | | | | | | |
| PPA energy revenues | 930 | | 168 | | 72 | | 8 | | 694 | | — | |
| PPA capacity revenues | 268 | | 78 | | 23 | | 3 | | 166 | | — | |
| Non-PPA revenues | 124 | | 99 | | 15 | | 271 | | 269 | | — | |
| Total wholesale electric revenues | 1,322 | | 345 | | 110 | | 282 | | 1,129 | | — | |
| Other natural gas revenues | | | | | | |
| | | | | | |
| | | | | | |
| Gas marketing services | 333 | | — | | — | | — | | — | | 333 | |
| Other natural gas revenues | 26 | | — | | — | | — | | — | | 26 | |
| Total natural gas revenues | 359 | | — | | — | | — | | — | | 359 | |
| Other revenues | 530 | | 109 | | 216 | | 17 | | 17 | | — | |
| Total revenue from contracts with customers | 12,486 | | 3,188 | | 4,674 | | 746 | | 1,146 | | 3,105 | |
Other revenue sources(a) | 1,368 | | 392 | | 654 | | 23 | | 292 | | 35 | |
| | | | | | |
| Total operating revenues | $ | 13,854 | | $ | 3,580 | | $ | 5,328 | | $ | 769 | | $ | 1,438 | | $ | 3,140 | |
| | | | | | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | | | | | | | |
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas |
| (in millions) |
| Three Months Ended June 30, 2021 | | | | | | |
| Operating revenues | | | | | | |
| Retail electric revenues | | | | | | |
| Residential | $ | 1,469 | | $ | 553 | | $ | 852 | | $ | 64 | | $ | — | | $ | — | |
| Commercial | 1,176 | | 386 | | 724 | | 66 | | — | | — | |
| Industrial | 728 | | 334 | | 321 | | 73 | | — | | — | |
| Other | 23 | | 4 | | 17 | | 2 | | — | | — | |
| Total retail electric revenues | 3,396 | | 1,277 | | 1,914 | | 205 | | — | | — | |
| Natural gas distribution revenues | | | | | | |
| Residential | 311 | | — | | — | | — | | — | | 311 | |
| Commercial | 73 | | — | | — | | — | | — | | 73 | |
| Transportation | 247 | | — | | — | | — | | — | | 247 | |
| Industrial | 8 | | — | | — | | — | | — | | 8 | |
| Other | 59 | | — | | — | | — | | — | | 59 | |
| Total natural gas distribution revenues | 698 | | — | | — | | — | | — | | 698 | |
| Wholesale electric revenues | | | | | | |
| PPA energy revenues | 209 | | 38 | | 16 | | 2 | | 158 | | — | |
| PPA capacity revenues | 118 | | 29 | | 14 | | 1 | | 75 | | — | |
| Non-PPA revenues | 55 | | 25 | | 3 | | 75 | | 78 | | — | |
| Total wholesale electric revenues | 382 | | 92 | | 33 | | 78 | | 311 | | — | |
| Other natural gas revenues | | | | | | |
| | | | | | |
| Wholesale gas services | 578 | | — | | — | | — | | — | | 578 | |
| Gas marketing services | 63 | | — | | — | | — | | — | | 63 | |
| Other natural gas revenues | 10 | | — | | — | | — | | — | | 10 | |
| Total natural gas revenues | 651 | | — | | — | | — | | — | | 651 | |
| Other revenues | 295 | | 52 | | 137 | | 7 | | 5 | | — | |
| Total revenue from contracts with customers | 5,422 | | 1,421 | | 2,084 | | 290 | | 316 | | 1,349 | |
Other revenue sources(a) | 1,179 | | 135 | | 141 | | 13 | | 174 | | 731 | |
Other adjustments(b) | (1,403) | | — | | — | | — | | — | | (1,403) | |
| Total operating revenues | $ | 5,198 | | $ | 1,556 | | $ | 2,225 | | $ | 303 | | $ | 490 | | $ | 677 | |
| | | | | | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | | | | | | | |
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas |
| (in millions) |
| Six Months Ended June 30, 2021 | | | | | | |
| Operating revenues | | | | | | |
| Retail electric revenues | | | | | | |
| Residential | $ | 2,936 | | $ | 1,181 | | $ | 1,627 | | $ | 128 | | $ | — | | $ | — | |
| Commercial | 2,294 | | 758 | | 1,410 | | 126 | | — | | — | |
| Industrial | 1,397 | | 654 | | 606 | | 137 | | — | | — | |
| Other | 47 | | 9 | | 34 | | 4 | | — | | — | |
| Total retail electric revenues | 6,674 | | 2,602 | | 3,677 | | 395 | | — | | — | |
| Natural gas distribution revenues | | | | | | |
| Residential | 925 | | — | | — | | — | | — | | 925 | |
| Commercial | 243 | | — | | — | | — | | — | | 243 | |
| Transportation | 536 | | — | | — | | — | | — | | 536 | |
| Industrial | 24 | | — | | — | | — | | — | | 24 | |
| Other | 155 | | — | | — | | — | | — | | 155 | |
| Total natural gas distribution revenues | 1,883 | | — | | — | | — | | — | | 1,883 | |
| Wholesale electric revenues | | | | | | |
| PPA energy revenues | 422 | | 81 | | 30 | | 7 | | 313 | | — | |
| PPA capacity revenues | 237 | | 58 | | 27 | | 4 | | 150 | | — | |
| Non-PPA revenues | 119 | | 57 | | 12 | | 162 | | 139 | | — | |
| Total wholesale electric revenues | 778 | | 196 | | 69 | | 173 | | 602 | | — | |
| Other natural gas revenues | | | | | | |
| | | | | | |
| Wholesale gas services | 2,168 | | — | | — | | — | | — | | 2,168 | |
| Gas marketing services | 257 | | — | | — | | — | | — | | 257 | |
| Other natural gas revenues | 17 | | — | | — | | — | | — | | 17 | |
| Total natural gas revenues | 2,442 | | — | | — | | — | | — | | 2,442 | |
| Other revenues | 542 | | 97 | | 249 | | 14 | | 9 | | — | |
| Total revenue from contracts with customers | 12,319 | | 2,895 | | 3,995 | | 582 | | 611 | | 4,325 | |
Other revenue sources(a) | 2,488 | | 220 | | 200 | | 28 | | 319 | | 1,745 | |
Other adjustments(b) | (3,699) | | — | | — | | — | | — | | (3,699) | |
| Total operating revenues | $ | 11,108 | | $ | 3,115 | | $ | 4,195 | | $ | 610 | | $ | 930 | | $ | 2,371 | |
(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
The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts with customers at June 30, 2022 and December 31, 2021:
| | | | | | | | | | | | | | | | | | | | |
| Southern Company | Alabama Power | Georgia Power | Mississippi Power | Southern Power | Southern Company Gas |
| (in millions) |
| Accounts Receivable | | | | | | |
| At June 30, 2022 | $ | 3,021 | | $ | 773 | | $ | 1,217 | | $ | 95 | | $ | 278 | | $ | 504 | |
| At December 31, 2021 | 2,504 | | 589 | | 736 | | 73 | | 149 | | 753 | |
| Contract Assets | | | | | | |
| At June 30, 2022 | $ | 102 | | $ | — | | $ | 38 | | $ | — | | $ | — | | $ | — | |
| At December 31, 2021 | 117 | | 2 | | 63 | | — | | 1 | | — | |
| Contract Liabilities | | | | | | |
| At June 30, 2022 | $ | 70 | | $ | 3 | | $ | 25 | | $ | 4 | | $ | 1 | | $ | — | |
| At December 31, 2021 | 57 | | 4 | | 14 | | — | | 1 | | — | |
At June 30, 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 $63 million and $50 million of contract assets and $38 million and $39 million of contract liabilities at June 30, 2022 and December 31, 2021, respectively, for outstanding performance obligations.
Revenues recognized in the three and six months ended June 30, 2022, which were included in contract liabilities at December 31, 2021, were $10 million and $19 million, respectively, for Southern Company and immaterial for the other Registrants.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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. For Southern Company Gas, these contracts involve energy infrastructure enhancement and upgrade projects for certain governmental customers. Southern Company's unregulated distributed generation business also has partially satisfied performance obligations related to certain fixed price contracts. Revenues from contracts with customers related to these performance obligations remaining at June 30, 2022 are expected to be recognized as follows:
| | | | | | | | | | | | | | | | | | | | |
| 2022 (remaining) | 2023 | 2024 | 2025 | 2026 | Thereafter |
| (in millions) |
| Southern Company | $ | 347 | | $ | 617 | | $ | 414 | | $ | 322 | | $ | 307 | | $ | 2,340 | |
| Alabama Power | 15 | | 24 | | 7 | | 5 | | — | | — | |
| Georgia Power | 39 | | 63 | | 30 | | 22 | | 11 | | 21 | |
| | | | | | |
| Southern Power | 184 | | 347 | | 344 | | 294 | | 299 | | 2,334 | |
| Southern Company Gas | 16 | | 29 | | 29 | | — | | — | | — | |
Revenue expected to be recognized for performance obligations remaining at June 30, 2022 was immaterial for Mississippi Power.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Lease Income
Lease income for the three and six months ended June 30, 2022 and 2021 is as follows:
| | | | | | | | | | | | | | | | | | | | |
| Southern
Company | Alabama Power | Georgia Power | Mississippi
Power | Southern Power | Southern Company Gas |
| | (in millions) |
For the Three Months Ended June 30, 2022 |
| Lease income - interest income on sales-type leases | $ | 7 | | $ | — | | $ | — | | $ | 4 | | $ | 3 | | $ | — | |
| Lease income - operating leases | 52 | | 19 | | 8 | | — | | 21 | | 9 | |
| Variable lease income | 129 | | — | | — | | — | | 138 | | — | |
| Total lease income | $ | 188 | | $ | 19 | | $ | 8 | | $ | 4 | | $ | 162 | | $ | 9 | |
| | | | | | |
For the Six Months Ended June 30, 2022 |
| Lease income - interest income on sales-type leases | $ | 13 | | $ | — | | $ | — | | $ | 8 | | $ | 5 | | $ | — | |
| Lease income - operating leases | 105 | | 39 | | 16 | | 1 | | 42 | | 18 | |
| Variable lease income | 211 | | — | | — | | — | | 227 | | — | |
| Total lease income | $ | 329 | | $ | 39 | | $ | 16 | | $ | 9 | | $ | 274 | | $ | 18 | |
| | | | | | |
For the Three Months Ended June 30, 2021 |
| Lease income - interest income on sales-type leases | $ | 4 | | $ | — | | $ | — | | $ | 4 | | $ | — | | $ | — | |
| Lease income - operating leases | 56 | | 21 | | 10 | | — | | 21 | | 9 | |
| Variable lease income | 128 | | (1) | | — | | — | | 138 | | — | |
| Total lease income | $ | 188 | | $ | 20 | | $ | 10 | | $ | 4 | | $ | 159 | | $ | 9 | |
| | | | | | |
For the Six Months Ended June 30, 2021 |
| Lease income - interest income on sales-type leases | $ | 7 | | $ | — | | $ | — | | $ | 7 | | $ | — | | $ | — | |
| Lease income - operating leases | 112 | | 41 | | 21 | | 1 | | 42 | | 17 | |
| Variable lease income | 212 | | — | | — | | — | | 228 | | — | |
| Total lease income | $ | 331 | | $ | 41 | | $ | 21 | | $ | 8 | | $ | 270 | | $ | 17 | |
Lease payments received under tolling arrangements and PPAs consist of either scheduled payments or variable payments based on the amount of energy produced by the underlying electric generating units. Lease income for Alabama Power and Southern Power is included in wholesale revenues.
(E) CONSOLIDATED ENTITIES AND EQUITY METHOD INVESTMENTS
See Note 7 to the financial statements in Item 8 of the Form 10-K for additional information.
Southern 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 June 30, 2022 and December 31, 2021, SP Solar had total assets of $6.0 billion and $6.1 billion, respectively, total liabilities of $386 million and $408 million, respectively, and noncontrolling interests of $1.1 billion. Cash distributions from SP Solar are allocated 67% to Southern Power and 33% to Global Atlantic in accordance with
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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 June 30, 2022 and December 31, 2021, SP Wind had total assets of $2.3 billion, total liabilities of $212 million and $130 million, respectively, and noncontrolling interests of $40 million and $41 million, respectively. Under the terms of the limited liability agreement, distributions without Class A member consent are limited to available cash and SP Wind is obligated to distribute all such available cash to its members each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves. Cash distributions from SP Wind are generally allocated 60% to Southern Power and 40% to the three financial investors in accordance with the limited liability agreement.
Southern Power consolidates both SP Solar and SP Wind, as the primary beneficiary, since it controls the most significant activities of each entity, including operating and maintaining their assets. Certain transfers and sales of the assets in the VIEs are subject to partner consent and the liabilities are non-recourse to the general credit of Southern Power. Liabilities consist of customary working capital items and do not include any long-term debt.
Other Variable Interest Entities
Southern Power has other consolidated VIEs that relate to certain subsidiaries that have either sold noncontrolling interests to tax equity investors or acquired less than a 100% interest from facility developers. These entities are considered VIEs because the arrangements are structured similar to a limited partnership and the noncontrolling members do not have substantive kick-out rights.
At June 30, 2022 and December 31, 2021, the other VIEs had total assets of $1.8 billion and $1.9 billion, respectively, total liabilities of $253 million and $263 million, respectively, and noncontrolling interests of $858 million and $886 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 June 30, 2022 and December 31, 2021, Southern Power had equity method investments in wind and battery energy storage projects totaling $49 million and $86 million, respectively. Earnings (loss) from these investments were immaterial for both periods presented. During the six months ended June 30, 2022, Southern Power sold equity method investments in wind projects and received proceeds totaling $38 million. The gains associated with the sales were immaterial.
Southern Company Gas
Equity Method Investments
The carrying amounts of Southern Company Gas' equity method investments at June 30, 2022 and December 31, 2021 and related earnings (loss) from those investments for the three and six months ended June 30, 2022 and 2021 were as follows:
| | | | | | | | |
| Investment Balance | June 30, 2022 | December 31, 2021 |
| (in millions) |
| SNG | $ | 1,099 | | $ | 1,129 | |
Other(*) | 35 | | 44 | |
| Total | $ | 1,134 | | $ | 1,173 | |
(*)Balance at June 30, 2022 reflects a $9 million distribution from PennEast Pipeline.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | | | | |
| Three Months Ended June 30, | | Six Months Ended June 30, |
| Earnings (Loss) from Equity Method Investments | 2022 | 2021 | | 2022 | 2021 |
| (in millions) |
| SNG | $ | 31 | | $ | 28 | | | $ | 70 | | $ | 66 | |
PennEast Pipeline(*) | — | | (81) | | | — | | (79) | |
| Other | — | | 1 | | | 1 | | 2 | |
| Total | $ | 31 | | $ | (52) | | | $ | 71 | | $ | (11) | |
(*)Includes a pre-tax impairment charge of $82 million ($58 million after tax) for the three and six months ended June 30, 2021. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.
(F) FINANCING AND LEASES
Bank Credit Arrangements
See Note 8 to the financial statements under "Bank Credit Arrangements" in Item 8 of the Form 10-K for additional information.
At June 30, 2022, committed credit arrangements with banks were as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Expires | | | | | | | | |
| Company | | 2023 | 2024 | 2025 | 2026 | | Total | | Unused | | | | | | | | Expires within
One Year |
| | (in millions) |
| Southern Company parent | | $ | — | | $ | — | | $ | — | | $ | 2,000 | | | $ | 2,000 | | | $ | 1,998 | | | | | | | | | $ | — | |
| Alabama Power | | — | | 550 | | — | | 700 | | | 1,250 | | | 1,250 | | | | | | | | | — | |
| Georgia Power | | — | | — | | — | | 1,750 | | | 1,750 | | | 1,726 | | | | | | | | | — | |
| Mississippi Power | | — | | 150 | | 125 | | — | | | 275 | | | 275 | | | | | | | | | — | |
Southern Power(a) | | — | | — | | — | | 600 | | | 600 | | | 568 | | | | | | | | | — | |
Southern Company Gas(b) | | 250 | | — | | — | | 1,500 | | | 1,750 | | | 1,748 | | | | | | | | | 250 | |
| SEGCO | | 30 | | — | | — | | — | | | 30 | | | 30 | | | | | | | | | 30 | |
| Southern Company | | $ | 280 | | $ | 700 | | $ | 125 | | $ | 6,550 | | | $ | 7,655 | | | $ | 7,595 | | | | | | | | | $ | 280 | |
(a)Does not include Southern Power Company's two $75 million continuing letter of credit facilities for standby letters of credit, expiring in 2023 and 2025, respectively, of which $11 million and $5 million, respectively, was unused at June 30, 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 $800 million of the credit arrangement expiring in 2026. Southern Company Gas' committed credit arrangement expiring in 2026 also includes $700 million for which Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. Pursuant to the multi-year credit arrangement expiring in 2026, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted. Nicor Gas is also the borrower of a new $250 million credit arrangement expiring in 2023.
As reflected in the table above, in March 2022, Mississippi Power amended and restated its $125 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
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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 June 30, 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.
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 June 30, 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 June 30, 2022, Georgia Power had approximately $445 million of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months.
Equity Units
In May 2022, Southern Company remarketed $862.5 million aggregate principal amount of its Series 2019A Remarketable Junior Subordinated Notes due August 1, 2024 (2019A RSNs) and $862.5 million aggregate principal amount of its Series 2019B Remarketable Junior Subordinated Notes due August 1, 2027 (2019B RSNs), pursuant to the terms of its 2019 Series A Equity Units (Equity Units). In connection with the remarketing, the interest rates on the 2019A RSNs and the 2019B RSNs were reset to 4.475% and 5.113%, respectively, payable on a semi-annual basis, and Southern Company ceased to have the ability to redeem these securities prior to maturity or to defer interest payments. Southern Company did not receive any proceeds from the remarketing, which were used to purchase a portfolio of treasury securities maturing on July 28, 2022. On August 1, 2022, the proceeds from this maturing portfolio will be used to settle the purchase contracts entered into as a part of the Equity Units and Southern Company expects to issue approximately 25.2 million shares of common stock. At June 30, 2022 and December 31, 2021, the 2019A RSNs and the 2019B RSNs are included in long-term debt on Southern Company's consolidated balance sheets.
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 and "Equity Units" herein 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. Shares used to compute diluted earnings per share were as follows:
| | | | | | | | | | | | | | |
| Three Months Ended June 30, | Six Months Ended June 30, |
| 2022 | 2021 | 2022 | 2021 |
| | (in millions) |
| As reported shares | 1,065 | | 1,061 | | 1,064 | | 1,060 | |
| Effect of stock-based compensation | 5 | | 6 | | 5 | | 6 | |
| Effect of equity units | 2 | | — | | 1 | | — | |
| Diluted shares | 1,072 | | 1,067 | | 1,070 | | 1,066 | |
For all periods presented, an immaterial number of stock-based compensation awards was not included in the diluted earnings per share calculation because the awards were anti-dilutive.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Southern Company Leveraged Lease
See Note 9 to the financial statements in Item 8 of the Form 10-K for information on a leveraged lease agreement related to energy generation. On June 30, 2022, the Southern Holdings subsidiary operating the generating plant for the lessee provided notice to the lessee to terminate the related operating and maintenance agreement effective June 30, 2023. The parties to the lease agreement are currently negotiating a potential restructuring, which could result in rescission of the termination notice. The ultimate outcome of this matter cannot be determined at this time but is not expected to have a material impact on Southern Company's financial statements.
Georgia Power Lease Modification
See Note 9 to the financial statements in Item 8 of the Form 10-K for information on Georgia Power's leases. Subsequent to June 30, 2022, Georgia Power recognized a lease modification related to an existing non-affiliate PPA which converted from an operating lease to a finance lease upon its approval in the 2022 IRP. As a result, Georgia Power will remove operating lease right-of-use assets, net of amortization of $17 million and lease obligations of $18 million maturing through 2024 and will record finance lease right-of-use assets of $110 million and lease obligations of $111 million maturing through 2039.
(G) INCOME TAXES
See Note 10 to the financial statements in Item 8 of the Form 10-K for additional tax information.
Current and Deferred Income Taxes
Tax Credit and Net Operating Loss Carryforwards
Southern Company had federal ITC and PTC carryforwards (primarily related to Southern Power) totaling $0.9 billion at June 30, 2022 compared to $1.2 billion at December 31, 2021.
The federal PTC and ITC carryforwards begin expiring in 2032, but are expected to be fully utilized by 2025. The utilization of each Registrant's estimated tax credit and state net operating loss carryforwards and related valuation allowances could be impacted by numerous factors, including the acquisition of additional renewable projects, the purchase of rights to additional PTCs of Plant Vogtle Units 3 and 4 pursuant to certain joint ownership agreements, an increase in Georgia Power's ownership interest percentage in Plant Vogtle Units 3 and 4, changes in taxable income projections, and potential income tax rate changes. See Note (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information on Plant Vogtle Units 3 and 4.
Effective Tax Rate
Southern Company's effective tax rate is typically lower than the statutory rate due to employee stock plans' dividend deduction, non-taxable AFUDC equity at the traditional electric operating companies, flowback of excess deferred income taxes at the regulated utilities, and federal income tax benefits from ITCs and PTCs primarily at Southern Power.
Details of significant changes in the effective tax rate for the applicable Registrants are provided herein.
Southern Company
Southern Company's effective tax rate was 18.7% for the six months ended June 30, 2022 compared to 10.7% for the corresponding period in 2021. The effective tax rate increase was primarily due to higher pre-tax earnings and an adjustment related to a prior year state tax credit carryforward at Georgia Power in 2022.
Georgia Power
Georgia Power's effective tax rate was 16.4% for the six months ended June 30, 2022 compared to a tax benefit rate of (6.9)% for the corresponding period in 2021. The effective tax rate increase was primarily due to higher pre-tax earnings and an adjustment related to a prior year state tax credit carryforward in 2022.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Mississippi Power
Mississippi Power's effective tax rate was 18.8% for the six months ended June 30, 2022 compared to 12.6% 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 in 2022.
Southern Power
Southern Power's effective tax rate was 11.2% for the six months ended June 30, 2022 compared to a tax benefit rate of (12.8)% for the corresponding period in 2021. The effective tax rate increase was primarily due to higher pre-tax earnings in 2022 and a change in state apportionment methodology resulting from tax legislation enacted by the State of Alabama in the first quarter 2021, partially offset by higher wind PTCs in 2022.
(H) RETIREMENT BENEFITS
The Southern Company system has a qualified defined benefit, trusteed, pension plan covering substantially all employees, with the exception of employees at PowerSecure. The qualified pension plan is funded in accordance with requirements of the Employee Retirement Income Security Act of 1974, as amended (ERISA). No mandatory contributions to the qualified pension plan are anticipated for the year ending December 31, 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. Components of the net periodic benefit costs for the three and six months ended June 30, 2022 and 2021 are presented in the following tables.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Southern
Company | | Alabama
Power | | Georgia
Power | | Mississippi
Power | | Southern Power | | Southern Company Gas |
| (in millions) |
| Three Months Ended June 30, 2022 | | | | | | | | | | |
| Pension Plans | | | | | | | | | | | |
| Service cost | $ | 103 | | | $ | 24 | | | $ | 26 | | | $ | 4 | | | $ | 3 | | | $ | 8 | |
| Interest cost | 102 | | | 24 | | | 30 | | | 4 | | | 1 | | | 7 | |
| Expected return on plan assets | (317) | | | (75) | | | (100) | | | (14) | | | (4) | | | (24) | |
| Amortization: | | | | | | | | | | | |
| Prior service costs | — | | | — | | | 1 | | | — | | | — | | | — | |
| Regulatory asset | — | | | — | | | — | | | — | | | — | | | 4 | |
| Net loss | 60 | | | 15 | | | 19 | | | 4 | | | — | | | 1 | |
| Net periodic pension cost (income) | $ | (52) | | | $ | (12) | | | $ | (24) | | | $ | (2) | | | $ | — | | | $ | (4) | |
| | | | | | | | | | | |
| Postretirement Benefits | | | | | | | | | | | |
| Service cost | $ | 5 | | | $ | 2 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | — | |
| Interest cost | 11 | | | 2 | | | 3 | | | 1 | | | — | | | 1 | |
| Expected return on plan assets | (20) | | | (8) | | | (6) | | | (1) | | | — | | | (1) | |
| Amortization: | | | | | | | | | | | |
| | | | | | | | | | | |
| Regulatory asset | — | | | — | | | — | | | — | | | — | | | 1 | |
| Net loss | — | | | — | | | 1 | | | — | | | — | | | — | |
| Net periodic postretirement benefit cost (income) | $ | (4) | | | $ | (4) | | | $ | (1) | | | $ | — | | | $ | — | | | $ | 1 | |
| | | | | | | | | | | |
| Six Months Ended June 30, 2022 | | | | | | | | | | |
| Pension Plans |
| Service cost | $ | 206 | | | $ | 49 | | | $ | 52 | | | $ | 8 | | | $ | 5 | | | $ | 17 | |
| Interest cost | 204 | | | 48 | | | 61 | | | 9 | | | 3 | | | 14 | |
| Expected return on plan assets | (633) | | | (152) | | | (199) | | | (29) | | | (8) | | | (46) | |
| Amortization: | | | | | | | | | | | |
| Prior service costs | — | | | — | | | 1 | | | — | | | — | | | (1) | |
| Regulatory asset | — | | | — | | | — | | | — | | | — | | | 8 | |
| Net loss | 120 | | | 31 | | | 37 | | | 7 | | | 1 | | | 3 | |
| Net periodic pension cost (income) | $ | (103) | | | $ | (24) | | | $ | (48) | | | $ | (5) | | | $ | 1 | | | $ | (5) | |
| | | | | | | | | | | |
| Postretirement Benefits |
| Service cost | $ | 11 | | | $ | 3 | | | $ | 3 | | | $ | — | | | $ | — | | | $ | 1 | |
| Interest cost | 21 | | | 5 | | | 7 | | | 1 | | | — | | | 2 | |
| Expected return on plan assets | (40) | | | (16) | | | (13) | | | (1) | | | — | | | (3) | |
| Amortization: | | | | | | | | | | | |
| | | | | | | | | | | |
| Regulatory asset | — | | | — | | | — | | | — | | | — | | | 3 | |
| Net (gain)/loss | — | | | — | | | 1 | | | — | | | — | | | (1) | |
| Net periodic postretirement benefit cost (income) | $ | (8) | | | $ | (8) | | | $ | (2) | | | $ | — | | | $ | — | | | $ | 2 | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Southern
Company | | Alabama
Power | | Georgia
Power | | Mississippi
Power | | Southern Power | | Southern Company Gas |
| (in millions) |
| Three Months Ended June 30, 2021 | | | | | | | | | | |
| Pension Plans |
| Service cost | $ | 108 | | | $ | 25 | | | $ | 28 | | | $ | 5 | | | $ | 3 | | | $ | 9 | |
| Interest cost | 86 | | | 21 | | | 26 | | | 4 | | | 1 | | | 6 | |
| Expected return on plan assets | (297) | | | (71) | | | (94) | | | (13) | | | (4) | | | (22) | |
| Amortization: | | | | | | | | | | | |
| Prior service costs | — | | | — | | | 1 | | | — | | | — | | | — | |
| Regulatory asset | — | | | — | | | — | | | — | | | — | | | 4 | |
| Net loss | 79 | | | 20 | | | 25 | | | 3 | | | 1 | | | 3 | |
| Net periodic pension cost (income) | $ | (24) | | | $ | (5) | | | $ | (14) | | | $ | (1) | | | $ | 1 | | | $ | — | |
| | | | | | | | | | | |
| Postretirement Benefits | | | | | | | | | | | |
| Service cost | $ | 6 | | | $ | 2 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | 1 | |
| Interest cost | 9 | | | 2 | | | 3 | | | 1 | | | — | | | 1 | |
| Expected return on plan assets | (19) | | | (7) | | | (6) | | | (1) | | | — | | | (2) | |
| Amortization: | | | | | | | | | | | |
| Prior service costs | (1) | | | — | | | — | | | — | | | — | | | — | |
| Regulatory asset | — | | | — | | | — | | | — | | | — | | | 1 | |
| Net loss | 1 | | | — | | | — | | | — | | | — | | | — | |
| Net periodic postretirement benefit cost (income) | $ | (4) | | | $ | (3) | | | $ | (2) | | | $ | — | | | $ | — | | | $ | 1 | |
| | | | | | | | | | | |
| Six Months Ended June 30, 2021 | | | | | | | | | | |
| Pension Plans |
| Service cost | $ | 217 | | | $ | 51 | | | $ | 56 | | | $ | 9 | | | $ | 5 | | | $ | 18 | |
| Interest cost | 173 | | | 41 | | | 52 | | | 8 | | | 2 | | | 12 | |
| Expected return on plan assets | (595) | | | (143) | | | (188) | | | (27) | | | (7) | | | (43) | |
| Amortization: | | | | | | | | | | | |
| Prior service costs | — | | | — | | | 1 | | | — | | | — | | | (1) | |
| Regulatory asset | — | | | — | | | — | | | — | | | — | | | 8 | |
| Net loss | 157 | | | 41 | | | 50 | | | 7 | | | 2 | | | 6 | |
| Net periodic pension cost (income) | $ | (48) | | | $ | (10) | | | $ | (29) | | | $ | (3) | | | $ | 2 | | | $ | — | |
| | | | | | | | | | | |
| Postretirement Benefits |
| Service cost | $ | 12 | | | $ | 3 | | | $ | 3 | | | $ | — | | | $ | — | | | $ | 1 | |
| Interest cost | 17 | | | 4 | | | 6 | | | 1 | | | — | | | 2 | |
| Expected return on plan assets | (38) | | | (14) | | | (13) | | | (1) | | | — | | | (4) | |
| Amortization: | | | | | | | | | | | |
| Prior service costs | (1) | | | — | | | — | | | — | | | — | | | — | |
| Regulatory asset | — | | | — | | | — | | | — | | | — | | | 3 | |
| Net (gain)/loss | 2 | | | — | | | 1 | | | — | | | — | | | (1) | |
| Net periodic postretirement benefit cost (income) | $ | (8) | | | $ | (7) | | | $ | (3) | | | $ | — | | | $ | — | | | $ | 1 | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
(I) FAIR VALUE MEASUREMENTS
At June 30, 2022, assets and liabilities measured at fair value on a recurring basis during the period, together with their associated level of the fair value hierarchy, were as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Fair Value Measurements Using: | | |
| At June 30, 2022 | Quoted Prices
in Active
Markets for
Identical
Assets
(Level 1) | | Significant
Other
Observable
Inputs
(Level 2) | | Significant
Unobservable
Inputs
(Level 3) | | Net Asset Value as a Practical Expedient (NAV) | | Total |
| (in millions) |
| Southern Company | | | | | | | | | |
| Assets: | | | | | | | | | |
Energy-related derivatives(a) | $ | 43 | | | $ | 408 | | | $ | — | | | $ | — | | | $ | 451 | |
| | | | | | | | | |
| | | | | | | | | |
Investments in trusts:(b)(c) | | | | | | | | | |
| Domestic equity | 643 | | | 168 | | | — | | | — | | | 811 | |
| Foreign equity | 122 | | | 144 | | | — | | | — | | | 266 | |
| U.S. Treasury and government agency securities | — | | | 273 | | | — | | | — | | | 273 | |
| Municipal bonds | — | | | 56 | | | — | | | — | | | 56 | |
| Pooled funds – fixed income | — | | | 9 | | | — | | | — | | | 9 | |
| Corporate bonds | 1 | | | 445 | | | — | | | — | | | 446 | |
| Mortgage and asset backed securities | — | | | 89 | | | — | | | — | | | 89 | |
| Private equity | — | | | — | | | — | | | 164 | | | 164 | |
| Cash and cash equivalents | 3 | | | — | | | — | | | — | | | 3 | |
| Other | 36 | | | 17 | | | — | | | — | | | 53 | |
| Cash equivalents | 1,058 | | | 10 | | | — | | | — | | | 1,068 | |
| Other investments | 9 | | | 27 | | | — | | | — | | | 36 | |
| Total | $ | 1,915 | | | $ | 1,646 | | | $ | — | | | $ | 164 | | | $ | 3,725 | |
| Liabilities: | | | | | | | | | |
Energy-related derivatives(a) | $ | 16 | | | $ | 88 | | | $ | — | | | $ | — | | | $ | 104 | |
| Interest rate derivatives | — | | | 214 | | | — | | | — | | | 214 | |
| Foreign currency derivatives | — | | | 228 | | | — | | | — | | | 228 | |
| Contingent consideration | — | | | — | | | 14 | | | — | | | 14 | |
| Other | — | | | 13 | | | — | | | — | | | 13 | |
| Total | $ | 16 | | | $ | 543 | | | $ | 14 | | | $ | — | | | $ | 573 | |
| | | | | | | | | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Fair Value Measurements Using: | | |
| At June 30, 2022 | Quoted Prices
in Active
Markets for
Identical
Assets
(Level 1) | | Significant
Other
Observable
Inputs
(Level 2) | | Significant
Unobservable
Inputs
(Level 3) | | Net Asset Value as a Practical Expedient (NAV) | | Total |
| (in millions) |
| Alabama Power | | | | | | | | | |
| Assets: | | | | | | | | | |
| Energy-related derivatives | $ | — | | | $ | 131 | | | $ | — | | | $ | — | | | $ | 131 | |
| | | | | | | | | |
Nuclear decommissioning trusts:(b) | | | | | | | | | |
| Domestic equity | 391 | | | 159 | | | — | | | — | | | 550 | |
| Foreign equity | 122 | | | — | | | — | | | — | | | 122 | |
| U.S. Treasury and government agency securities | — | | | 17 | | | — | | | — | | | 17 | |
| Municipal bonds | — | | | 2 | | | — | | | — | | | 2 | |
| Corporate bonds | 1 | | | 227 | | | — | | | — | | | 228 | |
| Mortgage and asset backed securities | — | | | 20 | | | — | | | — | | | 20 | |
| Private equity | — | | | — | | | — | | | 164 | | | 164 | |
| Other | 20 | | | — | | | — | | | — | | | 20 | |
| Cash equivalents | 677 | | | 10 | | | — | | | — | | | 687 | |
| Other investments | — | | | 27 | | | — | | | — | | | 27 | |
| Total | $ | 1,211 | | | $ | 593 | | | $ | — | | | $ | 164 | | | $ | 1,968 | |
| Liabilities: | | | | | | | | | |
| Energy-related derivatives | $ | — | | | $ | 23 | | | $ | — | | | $ | — | | | $ | 23 | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| Georgia Power | | | | | | | | | |
| Assets: | | | | | | | | | |
| Energy-related derivatives | $ | — | | | $ | 137 | | | $ | — | | | $ | — | | | $ | 137 | |
| | | | | | | | | |
Nuclear decommissioning trusts:(b)(c) | | | | | | | | | |
| Domestic equity | 252 | | | 1 | | | — | | | — | | | 253 | |
| Foreign equity | — | | | 142 | | | — | | | — | | | 142 | |
| U.S. Treasury and government agency securities | — | | | 256 | | | — | | | — | | | 256 | |
| Municipal bonds | — | | | 54 | | | — | | | — | | | 54 | |
| Corporate bonds | — | | | 218 | | | — | | | — | | | 218 | |
| Mortgage and asset backed securities | — | | | 69 | | | — | | | — | | | 69 | |
| Other | 16 | | | 17 | | | — | | | — | | | 33 | |
| Cash equivalents | 98 | | | — | | | — | | | — | | | 98 | |
| Total | $ | 366 | | | $ | 894 | | | $ | — | | | $ | — | | | $ | 1,260 | |
| Liabilities: | | | | | | | | | |
| Energy-related derivatives | $ | — | | | $ | 29 | | | $ | — | | | $ | — | | | $ | 29 | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Fair Value Measurements Using: | | |
| At June 30, 2022 | 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 | $ | — | | | $ | 121 | | | $ | — | | | $ | — | | | $ | 121 | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| Liabilities: | | | | | | | | | |
| Energy-related derivatives | $ | — | | | $ | 14 | | | $ | — | | | $ | — | | | $ | 14 | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| Southern Power | | | | | | | | | |
| Assets: | | | | | | | | | |
| Energy-related derivatives | $ | — | | | $ | 6 | | | $ | — | | | $ | — | | | $ | 6 | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| Liabilities: | | | | | | | | | |
| Energy-related derivatives | $ | — | | | $ | 1 | | | $ | — | | | $ | — | | | $ | 1 | |
| Foreign currency derivatives | — | | | 45 | | | — | | | — | | | 45 | |
| Contingent consideration | — | | | — | | | 14 | | | — | | | 14 | |
| Other | — | | | 13 | | | — | | | — | | | 13 | |
| Total | $ | — | | | $ | 59 | | | $ | 14 | | | $ | — | | | $ | 73 | |
| | | | | | | | | |
| Southern Company Gas | | | | | | | | | |
| Assets: | | | | | | | | | |
Energy-related derivatives(a) | $ | 43 | | | $ | 13 | | | $ | — | | | $ | — | | | $ | 56 | |
| | | | | | | | | |
| Non-qualified deferred compensation trusts: | | | | | | | | | |
| Domestic equity | — | | | 8 | | | — | | | — | | | 8 | |
| Foreign equity | — | | | 2 | | | — | | | — | | | 2 | |
| Pooled funds – fixed income | — | | | 9 | | | — | | | — | | | 9 | |
| Cash equivalents | 3 | | | — | | | — | | | — | | | 3 | |
| Cash equivalents and restricted cash | 192 | | | — | | | — | | | — | | | 192 | |
| | | | | | | | | |
| Total | $ | 238 | | | $ | 32 | | | $ | — | | | $ | — | | | $ | 270 | |
| Liabilities: | | | | | | | | | |
Energy-related derivatives(a) | $ | 16 | | | $ | 20 | | | $ | — | | | $ | — | | | $ | 36 | |
| Interest rate derivatives | — | | | 62 | | | — | | | — | | | 62 | |
| | | | | | | | | |
| Total | $ | 16 | | | $ | 82 | | | $ | — | | | $ | — | | | $ | 98 | |
(a)Excludes cash collateral of $13 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 June 30, 2022, approximately $65 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. The fair value of the funds, including reinvested interest and dividends and excluding the funds' expenses, increased (decreased) by the amounts shown in the table below for the three and six months ended June 30, 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.
| | | | | | | | | | | | | | |
| Fair value increases (decreases) | Three Months Ended June 30, 2022 | Three Months Ended June 30, 2021 | Six Months Ended June 30, 2022 | Six Months Ended June 30, 2021 |
| (in millions) |
| Southern Company | $ | (230) | | $ | 125 | | $ | (380) | | $ | 164 | |
| Alabama Power | (125) | | 77 | | (192) | | 118 | |
| Georgia Power | (105) | | 48 | | (188) | | 46 | |
Valuation Methodologies
The energy-related derivatives primarily consist of exchange-traded and over-the-counter financial products for natural gas and physical power products, including, from time to time, basis swaps. These are standard products used within the energy industry and are valued using the market approach. The inputs used are mainly from observable market sources, such as forward natural gas prices, power prices, implied volatility, and overnight index swap interest rates. Interest rate derivatives are also standard over-the-counter products that are valued using observable market data and assumptions commonly used by market participants. The fair value of interest rate derivatives reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future interest rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and occasionally, implied volatility of interest rate options. The fair value of cross-currency swaps reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future foreign currency exchange rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and discount rates. The interest rate derivatives and cross-currency swaps are categorized as Level 2 under Fair Value Measurements as these inputs are based on observable data and valuations of similar instruments. See Note (J) for additional information on how these derivatives are used.
For fair value measurements of the investments within the nuclear decommissioning trusts and the non-qualified deferred compensation trusts, external pricing vendors are designated for each asset class with each security specifically assigned a primary pricing source. For investments held within commingled funds, fair value is determined at the end of each business day through the net asset value, which is established by obtaining the underlying securities' individual prices from the primary pricing source. A market price secured from the primary source vendor is then evaluated by management in its valuation of the assets within the trusts. As a general approach, fixed income market pricing vendors gather market data (including indices and market research reports) and integrate relative credit information, observed market movements, and sector news into proprietary pricing models, pricing systems, and mathematical tools. Dealer quotes and other market information, including live trading levels and pricing analysts' judgments, are also obtained when available.
The NRC requires licensees of commissioned nuclear power reactors to establish a plan for providing reasonable assurance of funds for future decommissioning. See Note 6 to the financial statements under "Nuclear Decommissioning" in Item 8 of the Form 10-K for additional information.
Southern Power has contingent payment obligations related to certain acquisitions whereby it is primarily obligated to make generation-based payments to the seller, which commenced at the commercial operation of the respective facility and continue through 2026. The obligations are categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable inputs for the forecasted facility generation in MW-hours, as well as other inputs such as a fixed dollar amount per MW-hour, and a discount rate. The fair value of
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
contingent consideration reflects the net present value of expected payments and any periodic change arising from forecasted generation is expected to be immaterial.
Southern Power also has payment obligations through 2040 whereby it must reimburse the transmission owners for interconnection facilities and network upgrades constructed to support connection of a Southern Power generating facility to the transmission system. The obligations are categorized as Level 2 under Fair Value Measurements as the fair value is determined using observable inputs for the contracted amounts and reimbursement period, as well as a discount rate. The fair value of the obligations reflects the net present value of expected payments.
"Other investments" include investments traded in the open market that have maturities greater than 90 days, which are categorized as Level 2 under Fair Value Measurements and are comprised of corporate bonds, bank certificates of deposit, treasury bonds, and/or agency bonds.
At June 30, 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 $164 million and unfunded commitments related to the private equity investments totaled $91 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.
At June 30, 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 | $ | 52.0 | | $ | 9.8 | | $ | 14.6 | | $ | 1.5 | | $ | 3.0 | | $ | 6.8 | |
| Fair value | 48.0 | | 9.0 | | 13.7 | | 1.3 | | 2.9 | | 6.2 | |
(*)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) DERIVATIVES
The Registrants are exposed to market risks, including commodity price risk, interest rate risk, weather risk, and occasionally foreign currency exchange rate risk. To manage the volatility attributable to these exposures, each company nets its exposures, where possible, to take advantage of natural offsets and enters into various derivative transactions for the remaining exposures pursuant to each company's policies in areas such as counterparty exposure and risk management practices. 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
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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.
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)
At June 30, 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(*) | 273 | | 2030 | | 2025 |
| Alabama Power | 65 | | 2026 | | — |
| Georgia Power | 75 | | 2025 | | — |
| Mississippi Power | 71 | | 2026 | | — |
| Southern Power | 4 | | 2030 | | — |
Southern Company Gas(*) | 58 | | 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 64.4 million mmBtu and short natural gas positions of 6.4 million mmBtu at June 30, 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 15 million mmBtu for Southern Company, which includes 4 million mmBtu for Alabama Power, 5 million mmBtu for Georgia Power, 2 million mmBtu for Mississippi Power, and 4 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 June 30, 2023 total $12 million for both Southern Company and Southern Company Gas and are immaterial for the 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.
At June 30, 2022, the following interest rate derivatives were outstanding:
| | | | | | | | | | | | | | | | | | | | | | | |
| Notional
Amount | | Interest
Rate
Received | Weighted
Average
Interest
Rate Paid | Hedge
Maturity
Date | | Fair Value Gain (Loss) at June 30, 2022 |
| | (in millions) | | | | | | (in millions) |
| Cash Flow Hedges of Existing Debt | | | | | | |
| Alabama Power | $ | 50 | | | — | 3.18% | August 2027 | | $ | — | |
| Southern Company Gas | 250 | | | — | 3.26% | August 2032 | | (5) | |
| Fair Value Hedges of Existing Debt | | | | | | |
| Southern Company parent | 400 | | | 1.75% | 1-month LIBOR + 0.68% | March 2028 | | (39) | |
| Southern Company parent | 1,000 | | | 3.70% | 1-month LIBOR + 2.36% | April
2030 | | (113) | |
| Southern Company Gas | 500 | | | 1.75% | 1-month LIBOR + 0.38% | January 2031 | | (57) | |
| Southern Company | $ | 2,200 | | | | | | | $ | (214) | |
For cash flow hedges of interest rate derivatives, the estimated pre-tax gains (losses) expected to be reclassified from accumulated OCI to interest expense for the 12-month period ending June 30, 2023 total $(16) million for Southern Company and are immaterial for the other Registrants. Deferred gains and losses related to interest rate derivatives are expected to be amortized into earnings through 2052 for Southern Company, Alabama Power, and Georgia Power, 2028 for Mississippi Power, and 2046 for Southern Company Gas.
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.
At June 30, 2022, the following foreign currency derivatives were outstanding:
| | | | | | | | | | | | | | | | | | | | |
| Pay Notional | Pay
Rate | Receive Notional | Receive
Rate | Hedge
Maturity Date | Fair Value Gain (Loss) at June 30, 2022 |
| (in millions) | | (in millions) | | | (in millions) |
| Fair Value Hedges of Existing Debt | | | | | |
| Southern Company parent | $ | 1,476 | | 3.39% | € | 1,250 | | 1.88% | September 2027 | $ | (183) | |
| | | | | | |
| Cash Flow Hedges of Existing Debt | | | | | |
| | | | | | |
| Southern Power | 564 | | 3.78% | 500 | | 1.85% | June 2026 | (45) | |
| | | | | | |
| | | | | | |
| Southern Company | $ | 2,040 | | | € | 1,750 | | | | $ | (228) | |
For cash flow hedges of foreign currency derivatives, the estimated pre-tax losses expected to be reclassified from accumulated OCI to earnings for the 12-month period ending June 30, 2023 are $11 million for Southern Company and Southern Power.
Derivative Financial Statement Presentation and Amounts
The Registrants enter into derivative contracts that may contain certain provisions that permit intra-contract netting of derivative receivables and payables for routine billing and offsets related to events of default and settlements. Southern Company and certain subsidiaries also utilize master netting agreements to mitigate exposure to counterparty credit risk. These agreements may contain provisions that permit netting across product lines and against cash collateral. The fair value amounts of derivative assets and liabilities on the balance sheets are presented net to the extent that there are netting arrangements or similar agreements with the counterparties.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets as follows:
| | | | | | | | | | | | | | |
| At June 30, 2022 | At December 31, 2021 |
| Derivative Category and Balance Sheet Location | Assets | Liabilities | Assets | Liabilities |
| (in millions) | (in millions) |
| Southern Company | | | | |
| Derivatives designated as hedging instruments for regulatory purposes | | | | |
| Energy-related derivatives: | | | | |
| Assets from risk management activities/Other current liabilities | $ | 267 | | $ | 49 | | $ | 129 | | $ | 30 | |
| Other deferred charges and assets/Other deferred credits and liabilities | 144 | | 37 | | 72 | | 6 | |
| | | | |
| | | | |
| Total derivatives designated as hedging instruments for regulatory purposes | $ | 411 | | $ | 86 | | $ | 201 | | $ | 36 | |
| Derivatives designated as hedging instruments in cash flow and fair value hedges | | | | |
| Energy-related derivatives: | | | | |
| Assets from risk management activities/Other current liabilities | $ | 17 | | $ | 5 | | $ | 7 | | $ | 5 | |
| Other deferred charges and assets/Other deferred credits and liabilities | 6 | | — | | 1 | | — | |
| Interest rate derivatives: | | | | |
| Assets from risk management activities/Other current liabilities | — | | 19 | | 19 | | — | |
| Other deferred charges and assets/Other deferred credits and liabilities | — | | 195 | | — | | 29 | |
| Foreign currency derivatives: | | | | |
| Assets from risk management activities/Other current liabilities | — | | 36 | | — | | 39 | |
| Other deferred charges and assets/Other deferred credits and liabilities | — | | 192 | | — | | 40 | |
| Total derivatives designated as hedging instruments in cash flow and fair value hedges | $ | 23 | | $ | 447 | | $ | 27 | | $ | 113 | |
| Derivatives not designated as hedging instruments | | | | |
| Energy-related derivatives: | | | | |
| Assets from risk management activities/Other current liabilities | $ | 15 | | $ | 12 | | $ | 9 | | $ | 4 | |
| Other deferred charges and assets/Other deferred credits and liabilities | 2 | | 1 | | 1 | | — | |
| | | | |
| Total derivatives not designated as hedging instruments | $ | 17 | | $ | 13 | | $ | 10 | | $ | 4 | |
| Gross amounts recognized | $ | 451 | | $ | 546 | | $ | 238 | | $ | 153 | |
Gross amounts offset(a) | (87) | | (74) | | (25) | | (28) | |
Net amounts recognized in the Balance Sheets(b) | $ | 364 | | $ | 472 | | $ | 213 | | $ | 125 | |
| | | | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | |
| At June 30, 2022 | At December 31, 2021 |
| Derivative Category and Balance Sheet Location | Assets | Liabilities | Assets | Liabilities |
| (in millions) | (in millions) |
| Alabama Power | | | | |
| Derivatives designated as hedging instruments for regulatory purposes | | | | |
| Energy-related derivatives: | | | | |
| Other current assets/Other current liabilities | $ | 76 | | $ | 6 | | $ | 30 | | $ | 9 | |
| Other deferred charges and assets/Other deferred credits and liabilities | 55 | | 17 | | 25 | | 2 | |
| Total derivatives designated as hedging instruments for regulatory purposes | $ | 131 | | $ | 23 | | $ | 55 | | $ | 11 | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| Gross amounts offset | (20) | | (20) | | (5) | | (5) | |
| Net amounts recognized in the Balance Sheets | $ | 111 | | $ | 3 | | $ | 50 | | $ | 6 | |
| | | | |
| Georgia Power | | | | |
| Derivatives designated as hedging instruments for regulatory purposes | | | | |
| Energy-related derivatives: | | | | |
| Assets from risk management activities/Other current liabilities | $ | 102 | | $ | 15 | | $ | 54 | | $ | 6 | |
| Other deferred charges and assets/Other deferred credits and liabilities | 35 | | 14 | | 21 | | 2 | |
| Total derivatives designated as hedging instruments for regulatory purposes | $ | 137 | | $ | 29 | | $ | 75 | | $ | 8 | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| Gross amounts offset | (21) | | (21) | | (8) | | (8) | |
| Net amounts recognized in the Balance Sheets | $ | 116 | | $ | 8 | | $ | 67 | | $ | — | |
| | | | |
| Mississippi Power | | | | |
| Derivatives designated as hedging instruments for regulatory purposes | | | | |
| Energy-related derivatives: | | | | |
| Assets from risk management activities/Other current liabilities | $ | 67 | | $ | 8 | | $ | 30 | | $ | 3 | |
| Other deferred charges and assets/Other deferred credits and liabilities | 54 | | 6 | | 26 | | 2 | |
| Total derivatives designated as hedging instruments for regulatory purposes | $ | 121 | | $ | 14 | | $ | 56 | | $ | 5 | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| Gross amounts offset | (11) | | (11) | | (4) | | (4) | |
| Net amounts recognized in the Balance Sheets | $ | 110 | | $ | 3 | | $ | 52 | | $ | 1 | |
| | | | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | |
| At June 30, 2022 | At December 31, 2021 |
| Derivative Category and Balance Sheet Location | Assets | Liabilities | Assets | Liabilities |
| (in millions) | (in millions) |
| Southern Power | | | | |
| Derivatives designated as hedging instruments in cash flow and fair value hedges | | | | |
| Energy-related derivatives: | | | | |
| Other current assets/Other current liabilities | $ | — | | $ | — | | $ | 2 | | $ | — | |
| Other deferred charges and assets/Other deferred credits and liabilities | 4 | | — | | 1 | | — | |
| Foreign currency derivatives: | | | | |
| Other current assets/Other current liabilities | — | | 11 | | — | | 16 | |
| Other deferred charges and assets/Other deferred credits and liabilities | — | | 34 | | — | | — | |
| Total derivatives designated as hedging instruments in cash flow and fair value hedges | $ | 4 | | $ | 45 | | $ | 3 | | $ | 16 | |
| Derivatives not designated as hedging instruments | | | | |
| Energy-related derivatives: | | | | |
| Other current assets/Other current liabilities | $ | 1 | | $ | 1 | | $ | 1 | | $ | — | |
| Other deferred charges and assets/Other deferred credits and liabilities | 1 | | — | | — | | — | |
| | | | |
| | | | |
| Total derivatives not designated as hedging instruments | $ | 2 | | $ | 1 | | $ | 1 | | $ | — | |
| Gross amounts recognized | $ | 6 | | $ | 46 | | $ | 4 | | $ | 16 | |
| Gross amounts offset | (1) | | (1) | | — | | — | |
| Net amounts recognized in the Balance Sheets | $ | 5 | | $ | 45 | | $ | 4 | | $ | 16 | |
| | | | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | |
| At June 30, 2022 | At December 31, 2021 |
| Derivative Category and Balance Sheet Location | Assets | Liabilities | Assets | Liabilities |
| (in millions) | (in millions) |
| Southern Company Gas | | | | |
| Derivatives designated as hedging instruments for regulatory purposes | | | | |
| Energy-related derivatives: | | | | |
| Assets from risk management activities/Other current liabilities | $ | 23 | | $ | 19 | | $ | 15 | | $ | 12 | |
| | | | |
| Total derivatives designated as hedging instruments for regulatory purposes | $ | 23 | | $ | 19 | | $ | 15 | | $ | 12 | |
| Derivatives designated as hedging instruments in cash flow and fair value hedges | | | | |
| Energy-related derivatives: | | | | |
| Assets from risk management activities/Other current liabilities | $ | 17 | | $ | 5 | | $ | 5 | | $ | 5 | |
| Other deferred charges and assets/Other deferred credits and liabilities | 2 | | — | | — | | — | |
| Interest rate derivatives: | | | | |
| Assets from risk management activities/Liabilities from risk management activities-current | — | | — | | 6 | | — | |
| Other deferred charges and assets/Other deferred credits and liabilities | — | | 62 | | — | | 6 | |
| Total derivatives designated as hedging instruments in cash flow and fair value hedges | $ | 19 | | $ | 67 | | $ | 11 | | $ | 11 | |
| Derivatives not designated as hedging instruments | | | | |
| Energy-related derivatives: | | | | |
| Assets from risk management activities/Other current liabilities | $ | 13 | | $ | 11 | | $ | 8 | | $ | 4 | |
| Other deferred charges and assets/Other deferred credits and liabilities | 1 | | 1 | | 1 | | — | |
| | | | |
| Total derivatives not designated as hedging instruments | $ | 14 | | $ | 12 | | $ | 9 | | $ | 4 | |
| Gross amounts recognized | $ | 56 | | $ | 98 | | $ | 35 | | $ | 27 | |
Gross amounts offset(a) | (34) | | (21) | | (8) | | (11) | |
Net amounts recognized in the Balance Sheets(b) | $ | 22 | | $ | 77 | | $ | 27 | | $ | 16 | |
(a)Gross amounts offset include cash collateral held on deposit in broker margin accounts of $13 million and $3 million at June 30, 2022 and December 31, 2021, respectively.
(b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives at December 31, 2021. There were no such amounts at June 30, 2022.
Energy-related derivatives not designated as hedging instruments were immaterial for the traditional electric operating companies at June 30, 2022. There were no such instruments for the traditional electric operating companies at December 31, 2021.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
At June 30, 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 |
Derivative Category and Balance Sheet
Location | Southern
Company | Alabama
Power | Georgia
Power | Mississippi
Power | Southern Company Gas |
| | (in millions) |
At June 30, 2022: | | | | | |
| Energy-related derivatives: | | | | | |
| Other regulatory assets, current | $ | (26) | | $ | (2) | | $ | (6) | | $ | (3) | | $ | (15) | |
| Other regulatory assets, deferred | (3) | | (1) | | (1) | | (1) | | — | |
| | | | | |
| | | | | |
| Other regulatory liabilities, current | 234 | | 72 | | 93 | | 62 | | 7 | |
| Other regulatory liabilities, deferred | 110 | | 39 | | 22 | | 49 | | — | |
| Total energy-related derivative gains (losses) | $ | 315 | | $ | 108 | | $ | 108 | | $ | 107 | | $ | (8) | |
| | | | | |
At December 31, 2021: | | | | | |
| Energy-related derivatives: | | | | | |
| Other regulatory assets, current | $ | (17) | | $ | (6) | | $ | — | | $ | — | | $ | (11) | |
| | | | | |
| Other regulatory liabilities, current | 107 | | 28 | | 48 | | 27 | | 4 | |
| Other regulatory liabilities, deferred | 65 | | 22 | | 19 | | 24 | | — | |
| Total energy-related derivative gains (losses) | $ | 155 | | $ | 44 | | $ | 67 | | $ | 51 | | $ | (7) | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI were as follows:
| | | | | | | | | | | | | | |
| Gain (Loss) Recognized in OCI on Derivative | For the Three Months Ended June 30, | For the Six Months Ended June 30, |
| 2022 | 2021 | 2022 | 2021 |
| (in millions) | (in millions) |
| Southern Company | | | | |
| Cash flow hedges: | | | | |
| Energy-related derivatives | $ | (1) | | $ | 16 | | $ | 41 | | $ | 20 | |
| Interest rate derivatives | 21 | | (1) | | 30 | | 2 | |
| Foreign currency derivatives | (74) | | 4 | | (102) | | (43) | |
Fair value hedges(*): | | | | |
| Foreign currency derivatives | (7) | | — | | (3) | | — | |
| Total | $ | (61) | | $ | 19 | | $ | (34) | | $ | (21) | |
| | | | |
| | | | |
| Georgia Power | | | | |
| | | | |
| Interest rate derivatives | $ | 19 | | $ | — | | $ | 31 | | $ | — | |
| | | | |
| | | | |
| | | | |
| Southern Power | | | | |
| Cash flow hedges: | | | | |
| Energy-related derivatives | $ | 2 | | $ | 5 | | $ | 7 | | $ | 8 | |
| | | | |
| Foreign currency derivatives | (74) | | 4 | | (102) | | (43) | |
| Total | $ | (72) | | $ | 9 | | $ | (95) | | $ | (35) | |
| Southern Company Gas | | | | |
| Cash flow hedges: | | | | |
| Energy-related derivatives | $ | (2) | | $ | 11 | | $ | 35 | | $ | 12 | |
| Interest rate derivatives | (5) | | — | | (5) | | — | |
| Total | $ | (7) | | $ | 11 | | $ | 30 | | $ | 12 | |
(*)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 and six months ended June 30, 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.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on income were as follows:
| | | | | | | | | | | | | | |
| Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships | For the Three Months Ended June 30, | For the Six Months Ended June 30, |
|
| 2022 | 2021 | 2022 | 2021 |
| (in millions) | (in millions) |
| Southern Company | | | | |
| Total cost of natural gas | $ | 452 | | $ | 231 | | $ | 1,546 | | $ | 814 | |
Gain (loss) on energy-related cash flow hedges(a) | 10 | | 1 | | 18 | | (2) | |
| Total depreciation and amortization | 913 | | 891 | | 1,805 | | 1,762 | |
Gain (loss) on energy-related cash flow hedges(a) | 4 | | 1 | | 6 | | 4 | |
| Total interest expense, net of amounts capitalized | (488) | | (450) | | (950) | | (901) | |
Gain (loss) on interest rate cash flow hedges(a) | (6) | | (7) | | (13) | | (14) | |
Gain (loss) on foreign currency cash flow hedges(a) | (7) | | (6) | | (13) | | (12) | |
Gain (loss) on interest rate fair value hedges(b) | (76) | | (3) | | (198) | | (12) | |
| Total other income (expense), net | 139 | | 101 | | 283 | | 160 | |
Gain (loss) on foreign currency cash flow hedges(a)(c) | (73) | | 17 | | (97) | | (43) | |
| Gain (loss) on foreign currency fair value hedges | (96) | | — | | (121) | | — | |
| Amount excluded from effectiveness testing recognized in earnings | 7 | | — | | 3 | | — | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| Southern Power | | | | |
| Total depreciation and amortization | $ | 131 | | $ | 132 | | $ | 251 | | $ | 251 | |
Gain (loss) on energy-related cash flow hedges(a) | 4 | | 1 | | 6 | | 4 | |
| Total interest expense, net of amounts capitalized | (36) | | (37) | | (73) | | (75) | |
Gain (loss) on foreign currency cash flow hedges(a) | (7) | | (6) | | (13) | | (12) | |
| Total other income (expense), net | 1 | | 1 | | 3 | | 8 | |
Gain (loss) on foreign currency cash flow hedges(a)(c) | (73) | | 17 | | (97) | | (43) | |
| Southern Company Gas | | | | |
| Total cost of natural gas | $ | 452 | | $ | 231 | | $ | 1,546 | | $ | 814 | |
Gain (loss) on energy-related cash flow hedges(a) | 10 | | — | | 18 | | (2) | |
| Total interest expense, net of amounts capitalized | (61) | | (59) | | (122) | | (118) | |
Gain (loss) on interest rate cash flow hedges(a) | (1) | | (1) | | (1) | | (1) | |
Gain (loss) on interest rate fair value hedges(b) | (22) | | 4 | | (57) | | 4 | |
(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 and six months ended June 30, 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)
At June 30, 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 |
| Balance Sheet Location of Hedged Items | At June 30, 2022 | At December 31, 2021 | | At June 30, 2022 | At December 31, 2021 |
| (in millions) | | (in millions) |
| Southern Company | | | | | |
| | | | | |
| Long-term debt | $ | (2,981) | | $ | (3,280) | | | $ | 192 | | $ | 9 | |
| | | | | |
| Southern Company Gas | | | | | |
| | | | | |
| Long-term debt | $ | (437) | | $ | (493) | | | $ | 59 | | $ | 2 | |
For the three and six months ended June 30, 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 June 30, | | Six Months Ended June 30, |
| Derivatives in Non-Designated Hedging Relationships | Statements of Income Location | 2022 | 2021 | | 2022 | 2021 |
| | (in millions) | | (in millions) |
| | | | | | |
| Energy-related derivatives: | Natural gas revenues(*) | $ | (15) | | $ | (103) | | | $ | (13) | | $ | (120) | |
| Cost of natural gas | (25) | | 9 | | | (5) | | 16 | |
| | | | | | |
| Total derivatives in non-designated hedging relationships | $ | (40) | | $ | (94) | | | $ | (18) | | $ | (104) | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | |
(*)Excludes immaterial gains (losses) recorded in natural gas revenues associated with weather derivatives for all periods presented.
For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of energy-related derivatives not designated as hedging instruments were immaterial for the other Registrants.
Contingent Features
The Registrants do not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There are certain derivatives that could require collateral, but not accelerated payment, in the event of various credit rating changes of certain Southern Company subsidiaries. At June 30, 2022, the Registrants had no collateral posted with derivative counterparties to satisfy these arrangements.
For the applicable Registrants, the fair value of interest rate and energy-related derivative liabilities with contingent features and the maximum potential collateral requirements arising from the credit-risk-related contingent features, at a rating below BBB- and/or Baa3, were immaterial at June 30, 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 continued participating in the Southern Company power pool through July 13, 2022.
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.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
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 June 30, 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 June 30, 2022, cash collateral held on deposit in broker margin accounts was $13 million.
The Registrants are exposed to losses related to financial instruments in the event of counterparties' nonperformance. The Registrants only enter into agreements and material transactions with counterparties that have investment grade credit ratings by Moody's and S&P or with counterparties who have posted collateral to cover potential credit exposure. The Registrants have also established risk management policies and controls to determine and monitor the creditworthiness of counterparties in order to mitigate their exposure to counterparty credit risk.
Southern Company Gas uses established credit policies to determine and monitor the creditworthiness of counterparties, including requirements to post collateral or other credit security, as well as the quality of pledged collateral. Collateral or credit security is most often in the form of cash or letters of credit from an investment-grade financial institution, but may also include cash or U.S. government securities held by a trustee. Prior to entering a physical transaction, Southern Company Gas assigns its counterparties an internal credit rating and credit limit based on the counterparties' Moody's, S&P, and Fitch ratings, commercially available credit reports, and audited financial statements. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary.
Southern Company Gas utilizes netting agreements whenever possible to mitigate exposure to counterparty credit risk. Netting agreements enable Southern Company Gas to net certain assets and liabilities by counterparty across product lines and against cash collateral, provided the netting and cash collateral agreements include such provisions. While the amounts due from, or owed to, counterparties are settled net, they are recorded on a gross basis on the balance sheet as energy marketing receivables and energy marketing payables.
The Registrants do not anticipate a material adverse effect on their respective financial statements as a result of counterparty nonperformance.
(K) ACQUISITIONS 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 six months ended June 30, 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.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | | | | |
| Project Facility | Resource | Approximate Nameplate Capacity (MW) | Location | COD | PPA Contract Period |
Projects Completed During the Six Months Ended June 30, 2022 |
Garland Solar Storage(a) | Battery energy storage system | 88 | Kern County, CA | September 2021 through February 2022(b) | 20 years |
Tranquillity Solar Storage(a) | Battery energy storage system | 72 | Fresno County, CA | November 2021 through March 2022(c) | 20 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 88 MWs, of which 73 MWs were placed in service in 2021 and 15 MWs were placed in service in February 2022.
(c)The facility has a total capacity of 72 MWs, of which 32 MWs were placed in service in 2021 and 40 MWs were placed in service in March 2022.
Southern Company Gas
On May 20, 2022, Southern Company Gas received the final $5 million contingent payment from Dominion Modular LNG Holdings, Inc. in connection with its 2020 sale of Pivotal LNG, Inc.
(L) SEGMENT AND RELATED INFORMATION
Southern Company
The primary businesses of the Southern Company system are electricity sales by the traditional electric operating companies and Southern Power and the distribution of natural gas by Southern Company Gas. The traditional electric operating companies are vertically integrated utilities providing electric service in three Southeastern states. Southern Power develops, constructs, acquires, owns, and manages power generation assets, including renewable energy and battery energy storage projects, and sells electricity at market-based rates in the wholesale market. Southern Company Gas distributes natural gas through its natural gas distribution utilities and is involved in several other complementary businesses including gas pipeline investments and gas marketing services. 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 $232 million and $337 million for the three and six months ended June 30, 2022, respectively, and $112 million and $193 million for the three and six months ended June 30, 2021, respectively. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies were immaterial for all periods presented. Revenues from sales of natural gas from Southern Company Gas (prior to its sale of Sequent) to Southern Power were $6 million and $18 million for the three and six months ended June 30, 2021, respectively. 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 and six months ended June 30, 2021, leveraged lease projects. All other inter-segment revenues are not material.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Financial data for business segments and products and services for the three and six months ended June 30, 2022 and 2021 was as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Electric Utilities | | | | |
| Traditional
Electric Operating
Companies | Southern
Power | Eliminations | Total | Southern Company Gas | All
Other | Eliminations | Consolidated |
| (in millions) |
| Three Months Ended June 30, 2022 | | | | | | | |
| Operating revenues | $ | 5,563 | | $ | 899 | | $ | (456) | | $ | 6,006 | | $ | 1,083 | | $ | 159 | | $ | (42) | | $ | 7,206 | |
Segment net income (loss)(a)(b) | 1,036 | | 98 | | — | | 1,134 | | 115 | | (137) | | (5) | | 1,107 | |
| Six Months Ended June 30, 2022 | | | | | | | |
| Operating revenues | $ | 9,778 | | $ | 1,438 | | $ | (700) | | $ | 10,516 | | $ | 3,140 | | $ | 283 | | $ | (85) | | $ | 13,854 | |
Segment net income (loss)(a)(b) | 1,811 | | 170 | | — | | 1,981 | | 433 | | (263) | | (12) | | 2,139 | |
| At June 30, 2022 | | | | | | | | |
| Goodwill | $ | — | | $ | 2 | | $ | — | | $ | 2 | | $ | 5,015 | | $ | 263 | | $ | — | | $ | 5,280 | |
| Total assets | 92,742 | | 13,402 | | (787) | | 105,357 | | 23,618 | | 2,457 | | (663) | | 130,769 | |
| Three Months Ended June 30, 2021 | | | | | | | |
| Operating revenues | $ | 4,031 | | $ | 490 | | $ | (114) | | $ | 4,407 | | $ | 677 | | $ | 154 | | $ | (40) | | $ | 5,198 | |
Segment net income (loss)(a)(b)(c) | 511 | | 36 | | — | | 547 | | (65) | | (108) | | (2) | | 372 | |
| Six Months Ended June 30, 2021 | | | | | | | |
| Operating revenues | $ | 7,795 | | $ | 930 | | $ | (201) | | $ | 8,524 | | $ | 2,371 | | $ | 288 | | $ | (75) | | $ | 11,108 | |
Segment net income (loss)(a)(b)(c)(d) | 1,267 | | 133 | | — | | 1,400 | | 333 | | (216) | | (9) | | 1,508 | |
| At December 31, 2021 | | | | | | | | |
| Goodwill | $ | — | | $ | 2 | | $ | — | | $ | 2 | | $ | 5,015 | | $ | 263 | | $ | — | | $ | 5,280 | |
| Total assets | 89,051 | | 13,390 | | (667) | | 101,774 | | 23,560 | | 2,975 | | (775) | | 127,534 | |
(a)Attributable to Southern Company.
(b)For the traditional electric operating companies, includes pre-tax charges at Georgia Power for estimated losses associated with the construction of Plant Vogtle Units 3 and 4 of $52 million ($39 million after tax) for the three and six months ended June 30, 2022 and $460 million ($343 million after tax) and $508 million ($379 million after tax) for the three and six months ended June 30, 2021, respectively. 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 Company Gas, includes a pre-tax impairment charge of $82 million ($58 million after tax) related to its equity method investment in the PennEast Pipeline project. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.
(d)For Southern Power, includes gains on wind turbine equipment contributed to various equity method investments totaling approximately $37 million pre-tax ($28 million after tax). See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.
Products and Services
| | | | | | | | | | | | | | |
| | Electric Utilities' Revenues |
| Retail | Wholesale | Other | Total |
| (in millions) |
| Three Months Ended June 30, 2022 | $ | 4,789 | | $ | 937 | | $ | 280 | | $ | 6,006 | |
| Three Months Ended June 30, 2021 | 3,599 | | 546 | | 262 | | 4,407 | |
| Six Months Ended June 30, 2022 | $ | 8,402 | | $ | 1,601 | | $ | 513 | | $ | 10,516 | |
| Six Months Ended June 30, 2021 | 6,941 | | 1,091 | | 492 | | 8,524 | |
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
| | | | | | | | | | | | | | | | | |
| | Southern Company Gas' Revenues |
| Gas
Distribution
Operations | Wholesale Gas Services(*) | Gas
Marketing
Services | Other | Total |
| (in millions) |
| Three Months Ended June 30, 2022 | $ | 975 | | $ | — | | $ | 92 | | $ | 16 | | $ | 1,083 | |
| Three Months Ended June 30, 2021 | 706 | | (110) | | 64 | | 17 | | 677 | |
| Six Months Ended June 30, 2022 | $ | 2,765 | | $ | — | | $ | 335 | | $ | 40 | | $ | 3,140 | |
| Six Months Ended June 30, 2021 | 1,898 | | 188 | | 259 | | 26 | | 2,371 | |
(*)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.
Southern Company Gas
Southern Company Gas manages its business through three reportable segments – gas distribution operations, gas pipeline investments, and gas marketing services. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' reportable segments also included wholesale gas services. The non-reportable segments are combined and presented as all other. See Note 15 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 four states.
Gas pipeline investments consists of joint ventures in natural gas pipeline investments including a 50% interest in SNG and a 50% joint ownership interest in the Dalton Pipeline. These natural gas pipelines enable the provision of diverse sources of natural gas supplies to the customers of Southern Company Gas. Gas pipeline investments also includes a 20% ownership interest in the PennEast Pipeline project, which was cancelled in September 2021. 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.
NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)
(UNAUDITED)
Business segment financial data for the three and six months ended June 30, 2022 and 2021 was as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Gas Distribution Operations | Gas Pipeline Investments | Wholesale Gas Services(a) | Gas Marketing Services | Total | All Other | Eliminations | Consolidated |
| (in millions) |
| Three Months Ended June 30, 2022 | | | | | | |
| Operating revenues | $ | 980 | | $ | 8 | | $ | — | | $ | 92 | | $ | 1,080 | | $ | 10 | | $ | (7) | | $ | 1,083 | |
| Segment net income (loss) | 92 | | 23 | | — | | 1 | | 116 | | (1) | | — | | 115 | |
| Six Months Ended June 30, 2022 | | | | | | |
| Operating revenues | $ | 2,782 | | $ | 16 | | $ | — | | $ | 335 | | $ | 3,133 | | $ | 26 | | $ | (19) | | $ | 3,140 | |
Segment net income (loss) | 306 | | 52 | | — | | 67 | | 425 | | 8 | | — | | 433 | |
Total assets at June 30, 2022 | 21,183 | | 1,433 | | — | | 1,554 | | 24,170 | | 11,999 | | (12,551) | | 23,618 | |
| Three Months Ended June 30, 2021 | | | | | | |
| Operating revenues | $ | 710 | | $ | 8 | | $ | (110) | | $ | 64 | | $ | 672 | | $ | 11 | | $ | (6) | | $ | 677 | |
Segment net income (loss)(b) | 80 | | (36) | | (112) | | 6 | | (62) | | (3) | | — | | (65) | |
| Six Months Ended June 30, 2021 | | | | | | | |
| Operating revenues | $ | 1,910 | | $ | 16 | | $ | 188 | | $ | 259 | | $ | 2,373 | | $ | 18 | | $ | (20) | | $ | 2,371 | |
Segment net income (loss)(b) | 263 | | (7) | | 14 | | 62 | | 332 | | 1 | | — | | 333 | |
Total assets at December 31, 2021 | 20,917 | | 1,467 | | 31 | | 1,556 | | 23,971 | | 12,114 | | (12,525) | | 23,560 | |
(a)As a result of the sale of Sequent, wholesale gas services is no longer a reportable segment for the three and six months ended June 30, 2022. Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and intercompany revenues is shown in the following table.
| | | | | | | | | | | | | | | | | |
| Third Party Gross Revenues | Intercompany Revenues | Total Gross Revenues | Less Gross Gas Costs | Operating Revenues |
| (in millions) |
| | | | | |
| Three Months Ended June 30, 2021 | $ | 1,292 | | $ | 27 | | $ | 1,319 | | $ | 1,429 | | $ | (110) | |
| | | | | |
| Six Months Ended June 30, 2021 | 3,881 | | 90 | | 3,971 | | 3,783 | | 188 | |
(b)For gas pipeline investments, includes a pre-tax impairment charge of $82 million ($58 million after tax) related to the equity method investment in the PennEast Pipeline project. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.
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Combined Management's Discussion and Analysis of Financial Condition and Results of Operations | |
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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
Alabama Power
On July 12, 2022, the Alabama PSC approved the following items:
•Alabama Power's petition for a certificate of convenience and necessity, which authorizes Alabama Power to complete the acquisition of the Calhoun Generating Station. This transaction is expected to close by September 30, 2022.
•An increase to Rate ECR effective with August 2022 billings, which is expected to result in an increase of approximately $310 million annually. The approved increase in the Rate ECR factor will have no significant effect on Alabama Power's net income, but will increase operating cash flows related to fuel cost recovery.
•Modifications to Rate NDR.
•An accounting order authorizing Alabama Power to create a reliability reserve separate from the NDR and transition the previous Rate NDR authority related to reliability expenditures to the reliability reserve. Alabama Power may make accruals to the reliability reserve if the NDR balance exceeds $35 million.
See Note (B) to the Condensed Financial Statements under "Alabama Power" herein for additional information.
Georgia Power
Plant Vogtle Units 3 and 4 Construction and Start-Up Status
Construction continues on Plant Vogtle Units 3 and 4 (with electric generating capacity of approximately 1,100 MWs each), in which Georgia Power currently holds a 45.7% ownership interest. Georgia Power's share of the total project capital cost forecast to complete Plant Vogtle Units 3 and 4, including contingency, through the end of the first quarter 2023 and the fourth quarter 2023, respectively, is $10.5 billion.
Fuel load for Unit 3 is projected during the fourth quarter 2022 with an in-service date projected during the first quarter 2023. Unit 3's projected schedule primarily depends on the volume and completion of construction remediation work, completion of work packages, including inspection records, and other documentation necessary
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
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 fourth quarter 2023 for Unit 4 is projected. Unit 4's projected schedule primarily depends on Unit 3 progress through fuel load, startup, and testing; overall construction productivity and production levels improving, particularly in electrical installation, including terminations; and appropriate levels of craft laborers, particularly electricians and pipefitters, being added and maintained. Any further delays could result in later in-service dates and cost increases.
During the first half of 2022, established construction contingency totaling $126 million was assigned to the base capital cost forecast for costs primarily associated with construction productivity, the pace of system turnovers, additional craft and support resources, and procurement for Units 3 and 4. Georgia Power also increased its total project capital cost forecast as of June 30, 2022 by adding $36 million to replenish construction contingency. After considering the significant level of uncertainty that exists regarding the future recoverability of these costs since the ultimate outcome of these matters is subject to the outcome of future assessments by management, as well as Georgia PSC decisions in future regulatory proceedings, Georgia Power recorded a pre-tax charge to income in the second quarter 2022 of $36 million ($27 million after tax) for the increase in the total project capital cost forecast. Georgia Power may request the Georgia PSC to evaluate those expenditures for rate recovery during the prudence review following the Unit 4 fuel load pursuant to the twenty-fourth VCM stipulation described in Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction – Regulatory Matters" herein.
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. Georgia Power recorded pre-tax charges to income in the fourth quarter 2021 and the second quarter 2022 of approximately $440 million ($328 million after tax) and $16 million ($12 million after tax), respectively, associated with these cost-sharing and tender provisions, which are 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 $480 million associated with these provisions based on the current project capital cost forecast. In October 2021, Georgia Power and the other Vogtle Owners entered into an agreement, which was modified on June 3, 2022, to clarify the process for the tender provisions of the Global Amendments to provide for a decision between 120 and 194 days after the tender option is triggered, which the other Vogtle Owners assert occurred on February 14, 2022, and would require the other Vogtle Owners to notify Georgia Power of their intent to exercise their tender options by August 27, 2022. On June 17, 2022 and July 26, 2022, OPC and Dalton, respectively, notified Georgia Power of their purported exercises of their tender options. On June 18, 2022, OPC and MEAG Power each filed a separate lawsuit against Georgia Power in the Superior Court of Fulton County, Georgia seeking a declaratory judgment that the starting dollar amount is $17.1 billion and that the cost-sharing and tender provisions have been triggered. On July 25, 2022, Georgia Power filed its answer in the lawsuit filed by MEAG Power and included counterclaims seeking a declaratory judgment that the starting dollar amount is $18.38 billion and that costs related to force majeure events are excluded prior to calculating the cost-sharing and tender provisions and when calculating Georgia Power's related financial obligations.
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.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
2022 Base Rate Case
On June 24, 2022, Georgia Power filed a base rate case (Georgia Power 2022 Base Rate Case) with the Georgia PSC. The filing proposes a three-year alternate rate plan with requested rate increases totaling $852 million, $107 million, and $45 million effective January 1, 2023, January 1, 2024, and January 1, 2025, respectively. Georgia Power expects the Georgia PSC to render a final decision in this matter on December 20, 2022. The ultimate outcome of this matter cannot be determined at this time. See Note (B) to the Condensed Financial Statements under "Georgia Power – Rate Plans – 2022 Base Rate Case" herein for additional information.
Integrated Resource Plan
On July 21, 2022, the Georgia PSC approved Georgia Power's triennial IRP (2022 IRP), as modified by a stipulated agreement among Georgia Power, the staff of the Georgia PSC, and certain intervenors and as further modified by the Georgia PSC. In the 2022 IRP decision, the Georgia PSC approved several requests, including the following:
•Decertification and retirement of Plant Wansley Units 1 and 2 (926 MWs based on 53.5% ownership) by August 31, 2022 and Plant Scherer Unit 3 (614 MWs based on 75% ownership) by December 31, 2028, as well as the reclassification to regulatory asset accounts of the remaining net book values of these units and any remaining unusable materials and supplies inventories upon retirement.
•Decertification and retirement of Plant Gaston Units 1 through 4 (500 MWs based on 50% ownership through SEGCO) by December 31, 2028. See Note 7 to the financial statements under "SEGCO" in Item 8 of the Form 10-K for additional information.
•Georgia Power's environmental compliance strategy, including approval of Georgia Power's plans to address CCR at its ash ponds and landfills.
The Georgia PSC deferred a decision on the requested decertification and retirement of Plant Bowen Units 1 and 2 (1,400 MWs) to the 2025 IRP.
See Note (B) to the Condensed Financial Statements under "Georgia Power – Integrated Resource Plans" herein for additional information.
Mississippi Power
On June 7, 2022, the Mississippi PSC approved Mississippi Power's annual retail PEP filing for 2022, resulting in an annual increase in revenues of approximately $18 million, or 1.9%. The rate increase became effective with the first billing cycle of April 2022 in accordance with the PEP rate schedule.
On May 26, 2022, Mississippi Power and Cooperative Energy executed an amended shared service agreement (SSA) under which Cooperative Energy will continue to decrease its use of Mississippi Power's generation services under the MRA tariff up to 2.5% annually through 2035. At June 30, 2022, Mississippi Power is serving approximately 400 MWs of Cooperative Energy's annual demand. Beginning in 2036, Cooperative Energy will provide 100% of its electricity requirements at the MRA delivery points under the tariff. Neither party has the option to cancel the amended SSA. On June 30, 2022, Mississippi Power filed a request with the FERC for approval of the amended SSA. Mississippi Power expects to remarket this capacity, including the potential development of future arrangements with Cooperative Energy.
On July 15, 2022, Mississippi Power filed a request with the FERC for a $23 million increase in annual wholesale base revenues under the MRA tariff effective July 15, 2022, subject to refund. The ultimate outcome of this matter cannot be determined at this time.
See Note (B) to the Condensed Financial Statements under "Mississippi Power" herein for additional information.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Southern Power
During the six months ended June 30, 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 June 30, 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 96% through 2026 and 92% through 2031, with an average remaining contract duration of approximately 13 years.
Southern Company Gas
On May 31, 2022, Virginia Natural Gas filed a notice of intent with the Virginia State Corporation Commission to file a base rate case later in the third quarter 2022.
On July 1, 2022, Atlanta Gas Light filed its annual GRAM update with the Georgia PSC. The filing requests an annual base rate increase of $53 million based on the projected 12-month period beginning January 1, 2023. Resolution of the GRAM filing is expected by December 28, 2022, with the new rates effective January 1, 2023.
The ultimate outcome of these matters cannot be determined at this time.
RESULTS OF OPERATIONS
Southern Company
Net Income
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $735 | | N/M | | $631 | | 41.8 |
N/M - Not meaningful
Consolidated net income attributable to Southern Company was $1.1 billion ($1.04 per share) in the second quarter 2022 compared to $0.4 billion ($0.35 per share) for the corresponding period in 2021. For year-to-date 2022, consolidated net income attributable to Southern Company was $2.1 billion ($2.01 per share) compared to $1.5 billion ($1.42 per share) for the corresponding period in 2021. The increases were primarily due to decreases of $304 million and $340 million in the second quarter and year-to-date 2022, respectively, in after-tax charges related to the construction of Plant Vogtle Units 3 and 4, an after-tax charge of $58 million in the second quarter 2021 related to the PennEast pipeline project at Southern Company Gas, an increase in retail electric revenues associated with rates and pricing and warmer weather, and an increase in natural gas revenues from base rate increases and continued infrastructure replacement. The second quarter 2021 net loss of $112 million at Sequent, which was sold on July 1, 2021, also contributed to the net income increase in the second quarter 2022. These increases were partially offset by higher non-fuel operations and maintenance costs.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Retail Electric Revenues
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $1,190 | | 33.1 | | $1,461 | | 21.0 |
In the second quarter 2022, retail electric revenues were $4.8 billion compared to $3.6 billion for the corresponding period in 2021. For year-to-date 2022, retail electric revenues were $8.4 billion compared to $6.9 billion for the corresponding period in 2021.
Details of the changes in retail electric revenues were as follows:
| | | | | | | | | | | | | | | | | | | | | | | |
| | Second Quarter 2022 | | Year-To-Date 2022 |
| (in millions) | | (% change) | | (in millions) | | (% change) |
| Retail electric – prior year | $ | 3,599 | | | | | $ | 6,941 | | | |
| Estimated change resulting from – | | | | | | | |
| Rates and pricing | 237 | | | 6.6 | % | | 293 | | | 4.2 | % |
| Sales growth | 66 | | | 1.9 | | | 85 | | | 1.2 | |
| Weather | 145 | | | 4.0 | | | 161 | | | 2.3 | |
| Fuel and other cost recovery | 742 | | | 20.6 | | | 922 | | | 13.3 | |
| Retail electric – current year | $ | 4,789 | | | 33.1 | % | | $ | 8,402 | | | 21.0 | % |
Revenues associated with changes in rates and pricing increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. The increases were primarily due to higher contributions from commercial and industrial customers with variable demand-driven pricing, base tariff increases in accordance with Georgia Power's 2019 ARP, and pricing effects associated with residential customer usage. 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 second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. Weather-adjusted residential KWH sales increased 1.0% in the second quarter 2022 when compared to the corresponding period in 2021 primarily due to strong customer growth, partially offset by decreased customer usage. Weather-adjusted residential KWH sales decreased 0.1% for year-to-date 2022 when compared to the corresponding period in 2021 and weather-adjusted commercial KWH sales increased 2.2% and 2.1% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 primarily due to impacts on customer usage from increased activity outside the home as customers return to pre-pandemic levels of activity. Increased customer growth largely offset the decrease in customer usage impacting year-to-date 2022 residential KWH sales and contributed to the increase in commercial KWH sales. Industrial KWH sales increased 3.7% and 2.8% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 primarily due to strength in the pipeline and paper sectors, partially offset by a decrease in the chemicals sector.
Fuel and other cost recovery revenues increased $742 million and $922 million in the second quarter and year-to-date 2022, respectively, compared to the corresponding periods in 2021 primarily due to higher fuel and purchased power costs and an increase in the volume of KWHs generated. Electric rates for the traditional electric operating companies include provisions to adjust billings for fluctuations in fuel costs, including the energy component of purchased power costs. Under these provisions, fuel revenues generally equal fuel expenses, including the energy component of PPA costs, and do not affect net income. The traditional electric operating companies each have one or more regulatory mechanisms to recover other costs such as environmental and other compliance costs, storm damage, new plants, and PPA capacity costs. See Note 2 to the financial statements in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein for additional information.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Wholesale Electric Revenues
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $391 | | 71.6 | | $510 | | 46.7 |
In the second quarter 2022, wholesale electric revenues were $937 million compared to $546 million for the corresponding period in 2021. For year-to-date 2022, wholesale electric revenues were $1.6 billion compared to $1.1 billion for the corresponding period in 2021. The increases were primarily due to increases of $376 million and $493 million in the second quarter and year-to-date 2022, respectively, in energy revenues as a result of fuel and purchased power price increases when compared to the corresponding periods in 2021 and an increase in the volume of KWHs sold primarily associated with sales under natural gas PPAs at Southern Power. In addition, increases in capacity revenues of $15 million and $18 million in the second quarter and year-to-date 2022, respectively, were primarily due to increased capacity sales under natural gas PPAs at Southern Power.
Wholesale electric revenues consist of revenues from PPAs and short-term opportunity sales. Wholesale electric revenues from PPAs (other than solar and wind PPAs) have both capacity and energy components. Capacity revenues generally represent the greatest contribution to net income and are designed to provide recovery of fixed costs plus a return on investment. Energy revenues will vary depending on fuel prices, the market prices of wholesale energy compared to the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. Energy sales from solar and wind PPAs do not have a capacity charge and customers either purchase the energy output of a dedicated renewable facility through an energy charge or through a fixed price related to the energy. As a result, the ability to recover fixed and variable operations and maintenance expenses is dependent upon the level of energy generated from these facilities, which can be impacted by weather conditions, equipment performance, transmission constraints, and other factors. Wholesale electric revenues at Mississippi Power include FERC-regulated municipal and rural association sales under cost-based tariffs as well as market-based sales. Short-term opportunity sales are made at market-based rates that generally provide a margin above the Southern Company system's variable cost to produce the energy.
Other Electric Revenues
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $17 | | 9.7 | | $24 | | 6.9 |
In the second quarter 2022, other electric revenues were $192 million compared to $175 million for the corresponding period in 2021. For year-to-date 2022, other electric revenues were $370 million compared to $346 million for the corresponding period in 2021. The increases in the second quarter and year-to-date 2022 were primarily due to increases of $19 million and $27 million, respectively, in transmission revenues, $5 million and $8 million, respectively, in cogeneration steam revenues associated with higher natural gas prices at Alabama Power, and $4 million and $5 million, respectively, in rent revenues at the traditional electric operating companies, partially offset by decreases of $12 million and $20 million, respectively, resulting from the termination of a transmission service contract at Georgia Power.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Natural Gas Revenues
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $406 | | 60.0 | | $769 | | 32.4 |
In the second quarter 2022, natural gas revenues were $1.1 billion compared to $677 million for the corresponding period in 2021. For year-to-date 2022, natural gas revenues were $3.1 billion compared to $2.4 billion for the corresponding period in 2021.
Details of the changes in natural gas revenues were as follows:
| | | | | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 | | Year-To-Date 2022 |
| (in millions) | | (% change) | | (in millions) | | (% change) |
| Natural gas revenues – prior year | $ | 677 | | | | | $ | 2,371 | | | |
| Estimated change resulting from – | | | | | | | |
| Infrastructure replacement programs and base rate changes | 46 | | | 6.8 | % | | 132 | | | 5.6 | % |
| Gas costs and other cost recovery | 239 | | | 35.3 | | | 783 | | | 33.0 | |
| Gas marketing services | (5) | | | (0.7) | | | 13 | | | 0.5 | |
| Wholesale gas services | 110 | | | 16.2 | | | (187) | | | (7.9) | |
| Other | 16 | | | 2.4 | | | 28 | | | 1.2 | |
| Natural gas revenues – current year | $ | 1,083 | | | 60.0 | % | | $ | 3,140 | | | 32.4 | % |
Revenues from infrastructure replacement programs and base rate changes at the natural gas distribution utilities increased in the second quarter and year-to-date 2022 compared to the corresponding periods in 2021 primarily due to rate increases at Nicor Gas, 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 second quarter and year-to-date 2022 compared to the corresponding periods 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 decreased in the second quarter 2022 compared to the corresponding period in 2021 due to unrealized hedge losses and warmer weather in the second quarter 2022. For year-to-date 2022, revenues increased compared to the corresponding period in 2021 due to higher commodity prices and higher sales to commercial customers.
The changes in revenues related to Southern Company Gas' wholesale gas services were 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.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Other Revenues
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $4 | | 2.0 | | $(18) | | (5.0) |
For year-to-date 2022, other revenues were $341 million compared to $359 million for the corresponding period in 2021. The decrease was primarily due to a net decrease of $22 million in unregulated sales at Georgia Power primarily due to the timing of revenue recognition for a large, ongoing power delivery construction and maintenance contract, partially offset by increases associated with more energy conservation projects performed in 2022.
Fuel and Purchased Power Expenses
| | | | | | | | | | | | | | | | | | | | | | | |
| | Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| | (change in millions) | | (% change) | | (change in millions) | | (% change) |
| Fuel | $ | 867 | | | 102.2 | | $ | 1,130 | | | 66.6 |
| Purchased power | 191 | | | 88.0 | | 216 | | | 50.9 |
| Total fuel and purchased power expenses | $ | 1,058 | | | | | $ | 1,346 | | | |
In the second quarter 2022, total fuel and purchased power expenses were $2.1 billion compared to $1.1 billion for the corresponding period in 2021. The increase was primarily the result of an $853 million increase in the average cost of fuel and purchased power and a $205 million increase in the volume of KWHs generated and purchased.
For year-to-date 2022, total fuel and purchased power expenses were $3.5 billion compared to $2.1 billion for the corresponding period in 2021. The increase was primarily the result of a $1.1 billion increase in the average cost of fuel and purchased power and a $239 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:
| | | | | | | | | | | | | | |
| Second Quarter 2022 | Second Quarter 2021 | Year-To-Date 2022 | Year-To-Date 2021 |
Total generation (in billions of KWHs)(a) | 46 | 43 | 92 | 86 |
Total purchased power (in billions of KWHs) | 6 | 4 | 11 | 8 |
Sources of generation (percent)(a) — | | | | |
| Gas | 49 | 47 | 47 | 46 |
| Coal | 22 | 22 | 23 | 23 |
| Nuclear | 16 | 18 | 16 | 18 |
| Hydro | 3 | 4 | 5 | 4 |
| Wind, Solar, and Other | 10 | 9 | 9 | 9 |
Cost of fuel, generated (in cents per net KWH)— | | | | |
Gas(a) | 5.59 | 2.58 | 4.60 | 2.56 |
| Coal | 3.50 | 2.87 | 3.30 | 2.85 |
| Nuclear | 0.72 | 0.75 | 0.72 | 0.75 |
Average cost of fuel, generated (in cents per net KWH)(a) | 4.13 | 2.28 | 3.50 | 2.27 |
Average cost of purchased power (in cents per net KWH)(b) | 7.83 | 5.65 | 6.90 | 5.37 |
(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 second quarter 2022, fuel expense was $1.7 billion compared to $0.8 billion for the corresponding period in 2021. The increase was primarily due to a 116.7% increase in the average cost of natural gas per KWH generated, a 23.2% decrease in the volume of KWHs generated by hydro, a 22.0% increase in the average cost of coal per KWH generated, a 10.4% increase in the volume of KWHs generated by natural gas, and a 9.0% increase in the volume of KWHs generated by coal.
For year-to-date 2022, fuel expense was $2.8 billion compared to $1.7 billion for the corresponding period in 2021. The increase was primarily due to a 79.7% increase in the average cost of natural gas per KWH generated, a 15.8% increase in the average cost of coal per KWH generated, a 7.6% increase in the volume of KWHs generated by natural gas, and a 5.8% increase in the volume of KWHs generated by coal, partially offset by a 9.8% increase in the volume of KWHs generated by hydro.
Purchased Power
In the second quarter 2022, purchased power expense was $408 million compared to $217 million for the corresponding period in 2021. The increase was primarily due to a 38.6% increase in the average cost per KWH purchased primarily due to higher natural gas and coal prices and a 55.3% increase in the volume of KWHs purchased.
For year-to-date 2022, purchased power expense was $640 million compared to $424 million for the corresponding period in 2021. The increase was primarily due to a 28.5% increase in the average cost per KWH purchased primarily due to higher natural gas and coal prices and a 29.4% 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.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Cost of Natural Gas
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $221 | | 95.7 | | $732 | | 89.9 |
Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, natural gas distribution rates include provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas and do not affect net income from the natural gas distribution utilities. Cost of natural gas at the natural gas distribution utilities represented 88% and 89% of the total cost of natural gas in the second quarter and year-to-date 2022, respectively.
In the second quarter 2022, cost of natural gas was $452 million compared to $231 million for the corresponding period in 2021. For year-to-date 2022, cost of natural gas was $1.5 billion compared to $814 million for the corresponding period in 2021. The increases reflect higher gas cost recovery as a result of increases of 153.2% and 119.4% in natural gas prices in the second quarter and year-to-date 2022, respectively, compared to the corresponding periods in 2021.
Cost of Other Sales
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $11 | | 10.7 | | $(2) | | (1.1) |
In the second quarter 2022, cost of other sales was $114 million compared to $103 million for the corresponding period in 2021. The increase was primarily due to increases of $14 million related to distributed infrastructure projects at PowerSecure, $7 million associated with unregulated merchandising and energy services expenses at Alabama Power, and $5 million related to unregulated construction and maintenance contracts at Mississippi Power, partially offset by a $16 million decrease associated with unregulated power delivery construction and maintenance projects at Georgia Power.
For year-to-date 2022, cost of other sales was $183 million compared to $185 million for the corresponding period in 2021. The decrease was primarily due to a decrease of $26 million associated with unregulated power delivery construction and maintenance projects at Georgia Power, largely offset by increases of $14 million related to distributed infrastructure projects at PowerSecure, $5 million related to unregulated construction and maintenance contracts at Mississippi Power, and $5 million associated with unregulated merchandising and energy services expenses at Alabama Power.
Other Operations and Maintenance Expenses
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $120 | | 8.3 | | $265 | | 9.4 |
In the second quarter 2022, other operations and maintenance expenses were $1.6 billion compared to $1.4 billion for the corresponding period in 2021. Other operations and maintenance expenses increased $124 million, excluding expenses related to Sequent in the second quarter 2021. The increase was primarily due to increases of $29 million in transmission and distribution expenses primarily related to line maintenance, $22 million in generation expenses primarily related to scheduled outage and maintenance costs, $13 million in compensation and benefit expenses, $9 million associated with more unregulated energy conservation projects in 2022 at Georgia Power, $8 million in expenses at Southern Company Gas passed through directly to customers, primarily related to bad debt, and $6 million in amortization of cloud software.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
For year-to-date 2022, other operations and maintenance expenses were $3.1 billion compared to $2.8 billion for the corresponding period in 2021. Excluding $53 million of expenses related to Sequent in 2021, other operations and maintenance expenses increased $318 million. The increase was primarily due to increases of $86 million in transmission and distribution expenses primarily related to line maintenance, $80 million in generation expenses primarily related to scheduled outage and maintenance costs, $24 million in expenses at Southern Company Gas passed through directly to customers, primarily related to bad debt, $23 million in compensation and benefit expenses, and $8 million in amortization of cloud software.
Depreciation and Amortization
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $22 | | 2.5 | | $43 | | 2.4 |
In the second quarter 2022, depreciation and amortization was $913 million compared to $891 million for the corresponding period in 2021. For year-to-date 2022, depreciation and amortization was $1.81 billion compared to $1.76 billion for the corresponding period in 2021. The increases were primarily due to additional plant in service.
Taxes Other Than Income Taxes
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $36 | | 11.5 | | $64 | | 9.7 |
In the second quarter 2022, taxes other than income taxes were $349 million compared to $313 million for the corresponding period in 2021. For year-to-date 2022, taxes other than income taxes were $721 million compared to $657 million for the corresponding period in 2021. The increases primarily reflect 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.
Estimated Loss on Plant Vogtle Units 3 and 4
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $(408) | | (88.7) | | $(456) | | (89.8) |
In the second quarter 2022 and 2021, Georgia Power recorded estimated probable losses on Plant Vogtle Units 3 and 4 of $52 million and $460 million, respectively. For year-to-date 2022 and 2021, Georgia Power recorded estimated probable losses on Plant Vogtle Units 3 and 4 totaling $52 million and $508 million, respectively. The losses reflect 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
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $(1) | | (9.1) | | $(21) | | (38.9) |
For year-to-date 2022, gain on dispositions, net was $33 million compared to $54 million for the corresponding period in 2021. The decrease reflects a $39 million gain at Southern Power primarily from contributions of wind turbine equipment to various equity method investments in 2021, partially offset by a $17 million gain from sales of
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
integrated transmission system assets at Georgia Power in 2022. See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.
Earnings (Loss) from Equity Method Investments
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $74 | | N/M | | $75 | | N/M |
N/M - Not meaningful
In the second quarter 2022, earnings from equity method investments were $34 million compared to a loss of $40 million for the corresponding period in 2021. For year-to-date 2022, earnings from equity method investments were $80 million compared to $5 million for the corresponding period in 2021. The increases were primarily due to a pre-tax impairment charge of $82 million in the second quarter 2021 related to the PennEast Pipeline project at Southern Company Gas. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (E) to the Condensed Financial Statements herein under "Southern Company Gas" for additional information.
Interest Expense, Net of Amounts Capitalized
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $38 | | 8.4 | | $49 | | 5.4 |
In the second quarter 2022, interest expense, net of amounts capitalized was $488 million compared to $450 million for the corresponding period in 2021. The increase was primarily due to higher average outstanding borrowings.
For year-to-date 2022, interest expense, net of amounts capitalized was $950 million compared to $901 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 second quarter 2021.
See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information on borrowings.
Other Income (Expense), Net
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $38 | | 37.6 | | $123 | | 76.9 |
In the second quarter 2022, other income (expense), net was $139 million compared to $101 million for the corresponding period in 2021. The increase was primarily due to charitable contributions of $26 million at Southern Company Gas in the second quarter 2021 and a $16 million increase in non-service cost-related retirement benefits income.
For year-to-date 2022, other income (expense), net was $283 million compared to $160 million for the corresponding period in 2021. The increase was primarily due to charitable contributions of $101 million at Southern Company Gas for year-to-date 2021 and a $30 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 (Benefit)
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $316 | | N/M | | $299 | | N/M |
N/M - Not meaningful
In the second quarter 2022, income tax expense was $304 million compared to income tax benefit of $12 million for the corresponding period in 2021. For year-to-date 2022, income taxes were $477 million compared to $178 million for the corresponding period in 2021. The increases were primarily due to an increase in pre-tax earnings and an adjustment in the second quarter 2022 related to a prior year state tax credit carryforward at Georgia Power. See Note (G) to the Condensed Financial Statements herein for additional information.
Net Loss Attributable to Noncontrolling Interests
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $22 | | N/M | | $34 | | N/M |
N/M - Not meaningful
Substantially all noncontrolling interests relate to renewable projects at Southern Power. In the second quarter 2022, net loss attributable to noncontrolling interests was $22 million compared to an immaterial loss for the corresponding period in 2021. For year-to-date 2022, net loss attributable to noncontrolling interests was $67 million compared to $33 million for the corresponding period in 2021. The increased losses attributable to noncontrolling interests were primarily due to higher HLBV loss allocations to Southern Power's tax equity partners, partially offset by higher income allocations to Southern Power's equity partners.
Alabama Power
Net Income
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $52 | | 15.7 | | $40 | | 5.8 |
Alabama Power's net income after dividends on preferred stock in the second quarter 2022 was $383 million compared to $331 million for the corresponding period in 2021. Alabama Power's net income after dividends on preferred stock for year-to-date 2022 was $730 million compared to $690 million for the corresponding period in 2021. These increases were primarily due to an increase in retail revenues associated with warmer weather in Alabama Power's service territory in the second quarter and year-to-date 2022 compared to the corresponding periods in 2021 and sales growth, partially offset by an increase in operations and maintenance expenses.
Retail Revenues
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $275 | | 20.3 | | $302 | | 11.2 |
In the second quarter 2022, retail revenues were $1.63 billion compared to $1.35 billion for the corresponding period in 2021. For year-to-date 2022, retail revenues were $3.01 billion compared to $2.71 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:
| | | | | | | | | | | | | | | | | | | | | | | |
| | Second Quarter 2022 | | Year-To-Date 2022 |
| (in millions) | | (% change) | | (in millions) | | (% change) |
| Retail – prior year | $ | 1,354 | | | | | $ | 2,706 | | | |
| Estimated change resulting from – | | | | | | | |
| Rates and pricing | 4 | | | 0.3 | % | | 3 | | | 0.1 | % |
| Sales growth | 19 | | | 1.4 | | | 34 | | | 1.3 | |
| Weather | 63 | | | 4.6 | | | 64 | | | 2.4 | |
| Fuel and other cost recovery | 189 | | | 14.0 | | | 201 | | | 7.4 | |
| Retail – current year | $ | 1,629 | | | 20.3 | % | | $ | 3,008 | | | 11.2 | % |
Revenues attributable to changes in sales increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. Weather-adjusted residential KWH sales decreased 1.4% and 0.3% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 primarily due to decreased customer usage. Weather-adjusted commercial KWH sales decreased 0.2% in the second quarter 2022 when compared to the corresponding period in 2021 primarily due to decreased customer usage. Weather-adjusted commercial KWH sales increased 0.4% for year-to-date 2022 when compared to the corresponding period in 2021 primarily due to customer growth. Industrial KWH sales increased 3.9% and 2.0% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 primarily due to increases in the pipeline, mining, and pulp and paper sectors, partially offset by decreases in the chemicals sector.
Fuel and other cost recovery revenues increased in the second quarter and year-to-date 2022 when compared to the corresponding periods 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
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $74 | | 87.1 | | $94 | | 52.8 |
In the second quarter 2022, wholesale revenues from sales to non-affiliates were $159 million compared to $85 million for the corresponding period in 2021. For year-to-date 2022, wholesale revenues from sales to non-affiliates were $272 million compared to $178 million for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to increases of 41.8% and 27.3%, respectively, in KWH sales as a result of increased opportunity sales due to warmer weather in the second quarter and year-to-date 2022 compared to the corresponding periods in 2021, as well as increases of 31.4% and 20.5%, respectively, 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
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $10 | | 41.7 | | $45 | | 81.8 |
In the second quarter 2022, wholesale revenues from sales to affiliates were $34 million compared to $24 million for the corresponding period in 2021. The increase was primarily due to a 154.8% increase in the price of energy due to higher natural gas prices, partially offset by a 42.5% decrease in KWH sales due to lower cost system resources compared to Alabama Power's generation.
For year-to-date 2022, wholesale revenues from sales to affiliates were $100 million compared to $55 million for the corresponding period in 2021. The increase was primarily due to a 72.1% increase in the price of energy due to higher natural gas prices and a 5.1% increase in KWH sales due to lower cost resources as compared to available affiliate company generation.
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.
Other Revenues
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $16 | | 17.2 | | $24 | | 13.6 |
In the second quarter 2022, other revenues were $109 million compared to $93 million for the corresponding period in 2021. For year-to-date 2022, other revenues were $200 million compared to $176 million for the corresponding period in 2021. The second quarter and year-to-date 2022 increases were primarily due to increases of $5 million and $8 million, respectively, in cogeneration steam revenue associated with higher natural gas prices, $4 million and $7 million, respectively, in transmission revenues, and $3 million and $4 million, respectively, in rent revenues.
Fuel and Purchased Power Expenses
| | | | | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| Fuel | $ | 138 | | | 52.5 | | | $ | 179 | | | 32.3 | |
| Purchased power – non-affiliates | 47 | | | 97.9 | | | 65 | | | 67.0 | |
| Purchased power – affiliates | 82 | | | 210.3 | | | 78 | | | 113.0 | |
| Total fuel and purchased power expenses | $ | 267 | | | | | $ | 322 | | | |
In the second quarter 2022, total fuel and purchased power expenses were $617 million compared to $350 million for the corresponding period in 2021. The increase was primarily due to a $199 million increase in the cost of fuel and purchased power and a $67 million increase related to the volume of KWHs generated and purchased.
For year-to-date 2022, total fuel and purchased power expenses were $1.04 billion compared to $720 million for the corresponding period in 2021. The increase was primarily due to a $235 million increase in the cost of fuel and purchased power and an $87 million increase related to the volume of KWHs generated and purchased.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
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.
Details of Alabama Power's generation and purchased power were as follows:
| | | | | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 | | Second Quarter 2021 | | Year-To-Date 2022 | | Year-To-Date 2021 |
Total generation (in billions of KWHs)(a) | 13 | | 13 | | 29 | | 28 |
Total purchased power (in billions of KWHs) | 3 | | 2 | | 4 | | 3 |
Sources of generation (percent)(a) — | | | | | | | |
| Coal | 45 | | 43 | | 44 | | 45 |
| Nuclear | 25 | | 25 | | 25 | | 25 |
| Gas | 22 | | 22 | | 20 | | 20 |
| Hydro | 8 | | 10 | | 11 | | 10 |
Cost of fuel, generated (in cents per net KWH) — | | | | | | | |
| Coal | 3.35 | | 2.73 | | 3.11 | | 2.74 |
| Nuclear | 0.67 | | 0.69 | | 0.67 | | 0.71 |
Gas(a) | 4.88 | | 2.47 | | 4.17 | | 2.49 |
Average cost of fuel, generated (in cents per net KWH)(a) | 2.98 | | 2.10 | | 2.66 | | 2.12 |
Average cost of purchased power (in cents per net KWH)(b) | 8.88 | | 5.57 | | 8.12 | | 5.99 |
(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 second quarter 2022, fuel expense was $401 million compared to $263 million for the corresponding period in 2021. The increase was primarily due to a 97.6% increase in the average cost of natural gas per KWH generated, which excludes tolling agreements, a 22.7% increase in the average cost of coal per KWH generated, a 5.2% increase in the volume of KWHs generated by coal, and a 24.7% decrease in the volume of KWHs generated by hydro facilities as a result of less rainfall in the second quarter 2022 compared to the corresponding period in 2021.
For year-to-date 2022, fuel expense was $733 million compared to $554 million for the corresponding period in 2021. The increase was primarily due to a 67.5% increase in the average cost of natural gas per KWH generated, which excludes tolling agreements, and a 13.5% increase in the average cost of coal per KWH generated, partially offset by a 12.7% increase in the volume of KWHs generated by hydro facilities as a result of more rainfall for year-to-date 2022 compared to the corresponding period in 2021.
Purchased Power – Non-Affiliates
In the second quarter 2022, purchased power expense from non-affiliates was $95 million compared to $48 million for the corresponding period in 2021. The increase was primarily due to a 67.4% increase in the volume of KWHs purchased as a result of warmer weather in the second quarter 2022 compared to the corresponding period in 2021, as well as a 32.6% increase in the average cost per KWH purchased due to higher natural gas and coal prices.
For year-to-date 2022, purchased power expense from non-affiliates was $162 million compared to $97 million for the corresponding period in 2021. The increase was primarily due to a 48.1% increase in the volume of KWHs purchased as a result of warmer weather for year-to-date 2022 compared to the corresponding period in 2021, as well as a 22.5% increase in the average cost per KWH purchased due to higher natural gas and coal prices.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Energy purchases from non-affiliates will vary depending on the market prices of wholesale energy as compared to the cost of the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation.
Purchased Power – Affiliates
In the second quarter 2022, purchased power expense from affiliates was $121 million compared to $39 million for the corresponding period in 2021. The increase was primarily due to a 102.3% increase in the average cost per KWH purchased due to higher natural gas and coal prices and a 54.4% increase in the volume of KWHs purchased as a result of warmer weather in the second quarter 2022 compared to the corresponding period in 2021.
For year-to-date 2022, purchased power expense from affiliates was $147 million compared to $69 million for the corresponding period in 2021. The increase was primarily due to a 61.5% increase in the average cost per KWH purchased due to higher natural gas and coal prices and a 32.1% increase in the volume of KWHs purchased as a result of warmer weather for year-to-date 2022 compared to the corresponding period in 2021.
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.
Other Operations and Maintenance Expenses
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $28 | | 6.8 | | $77 | | 9.9 |
In the second quarter 2022, other operations and maintenance expenses were $441 million compared to $413 million for the corresponding period in 2021. For year-to-date 2022, other operations and maintenance expenses were $852 million compared to $775 million for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to increases of $11 million and $39 million, respectively, in generation expenses associated with scheduled outages and maintenance and Rate CNP Compliance-related expenses, $9 million and $23 million, respectively, in transmission and distribution expenses primarily associated with line maintenance, and $3 million and $6 million, respectively, in customer service and sales expenses primarily associated with contract services. See Note 2 to the financial statements under "Alabama Power – Rate CNP Compliance" in Item 8 of the Form 10-K for additional information.
Interest Expense, Net of Amounts Capitalized
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $7 | | 8.3 | | $12 | | 7.1 |
For year-to-date 2022, interest expense, net of amounts capitalized was $180 million compared to $168 million for the corresponding period in 2021. The increase was primarily due to an increase associated with higher average outstanding borrowings. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information on borrowings.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Income Taxes
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $17 | | 16.3 | | $14 | | 6.6 |
In the second quarter 2022, income taxes were $121 million compared to $104 million for the corresponding period in 2021. For year-to-date 2022, income taxes were $227 million compared to $213 million for the corresponding period in 2021. The increases were primarily due to higher pre-tax earnings.
Georgia Power
Net Income
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $465 | | 325.2 | | $499 | | 101.0 |
Georgia Power's net income in the second quarter 2022 was $608 million compared to $143 million for the corresponding period in 2021. For year-to-date 2022 net income was $1.0 billion compared to $0.5 billion for the corresponding period in 2021. The increases were primarily due to increases in retail revenues associated with rates and pricing and warmer weather in Georgia Power's service territory in the second quarter and year-to-date 2022 compared to the corresponding periods in 2021 and decreases of $304 million and $340 million in the second quarter and year-to-date 2022, respectively, in after-tax charges 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
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $882 | | 43.5 | | $1,113 | | 29.2 |
In the second quarter 2022, retail revenues were $2.91 billion compared to $2.03 billion for the corresponding period in 2021. For year-to-date 2022, retail revenues were $4.93 billion compared to $3.81 billion for the corresponding period in 2021.
Details of the changes in retail revenues were as follows:
| | | | | | | | | | | | | | | | | | | | | | | |
| | Second Quarter 2022 | | Year-To-Date 2022 |
| (in millions) | | (% change) | | (in millions) | | (% change) |
| Retail – prior year | $ | 2,026 | | | | | $ | 3,813 | | | |
| Estimated change resulting from – | | | | | | | |
| Rates and pricing | 231 | | | 11.4 | % | | 285 | | | 7.5 | % |
| Sales growth | 45 | | | 2.2 | | | 47 | | | 1.2 | |
| Weather | 72 | | | 3.5 | | | 91 | | | 2.4 | |
| Fuel cost recovery | 534 | | | 26.4 | | | 690 | | | 18.1 | |
| Retail – current year | $ | 2,908 | | | 43.5 | % | | $ | 4,926 | | | 29.2 | % |
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Revenues associated with changes in rates and pricing increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. The increases were primarily due to higher contributions from commercial and industrial customers with variable demand-driven pricing, base tariff increases in accordance with the 2019 ARP, and pricing effects associated with residential customer usage. 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 second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. Weather-adjusted residential KWH sales increased 2.6% in the second quarter 2022 and were flat year-to-date 2022 and weather-adjusted commercial KWH sales increased 3.2% and 2.7% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 primarily due to the impacts on customer usage from increased activity outside the home following the expiration of COVID-19 restrictions and customer growth. Weather-adjusted industrial KWH sales increased 3.1% and 3.3% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 primarily due to increases in the paper and pipeline sectors, partially offset by a decrease in the chemicals sector.
Fuel revenues and costs are allocated between retail and wholesale jurisdictions. Retail fuel cost recovery revenues increased in the second quarter and year-to-date 2022 when compared to the corresponding periods 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
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $28 | | 77.8 | | $50 | | 62.5 |
In the second quarter 2022, wholesale revenues were $64 million compared to $36 million for the corresponding period in 2021. For year-to-date 2022, wholesale revenues were $130 million compared to $80 million for the corresponding period in 2021. The increases were primarily due to increases of $28 million and $46 million in the second quarter and year-to-date 2022, respectively, related to the average cost of fuel primarily due to higher natural gas and coal prices. Also contributing to the increase for year-to-date 2022 was a $6 million increase in KWH sales associated with higher market demand.
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
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $(14) | | (8.6) | | $(30) | | (9.9) |
In the second quarter 2022, other revenues were $149 million compared to $163 million for the corresponding period in 2021. For year-to-date 2022, other revenues were $272 million compared to $302 million for the corresponding period in 2021. The decreases for the second quarter and year-to-date 2022 were primarily due to decreases of $12 million and $20 million, respectively, resulting from the termination of a transmission service contract and net decreases of $8 million and $15 million, respectively, in unregulated sales primarily due to the timing of revenue recognition for a large, ongoing power delivery construction and maintenance contract, partially offset by increases associated with more energy conservation projects performed in 2022 and outdoor lighting sales growth. The decreases were also partially offset by increases of $9 million and $10 million, respectively, in open access transmission tariff sales.
Fuel and Purchased Power Expenses
| | | | | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-to-Date 2022 vs. Year-to-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| Fuel | $ | 285 | | | 83.1 | | | $ | 390 | | | 59.5 | |
| Purchased power – non-affiliates | 102 | | | 70.8 | | | 108 | | | 37.5 | |
| Purchased power – affiliates | 174 | | | 116.8 | | | 244 | | | 85.6 | |
| Total fuel and purchased power expenses | $ | 561 | | | | | $ | 742 | | | |
In the second quarter 2022, total fuel and purchased power expenses were $1.20 billion compared to $0.64 billion for the corresponding period in 2021. For year-to-date 2022, total fuel and purchased power expenses were $1.97 billion compared to $1.23 billion for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to increases of $474 million and $609 million, respectively, related to the average cost of fuel and purchased power and increases of $87 million and $133 million, respectively, 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.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Details of Georgia Power's generation and purchased power were as follows:
| | | | | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 | | Second Quarter 2021 | | Year-To-Date 2022 | | Year-To-Date 2021 |
Total generation (in billions of KWHs) | 15 | | 15 | | 30 | | 30 |
Total purchased power (in billions of KWHs) | 8 | | 7 | | 16 | | 14 |
Sources of generation (percent) — | | | | | | | |
| Gas | 45 | | 46 | | 45 | | 47 |
| | | | | | | |
| Nuclear | 27 | | 28 | | 25 | | 27 |
| Coal | 24 | | 22 | | 25 | | 22 |
| Hydro and other | 4 | | 4 | | 5 | | 4 |
Cost of fuel, generated (in cents per net KWH) — | | | | | | | |
| Gas | 5.10 | | 2.65 | | 4.34 | | 2.62 |
| Coal | 3.68 | | 3.09 | | 3.54 | | 3.01 |
| Nuclear | 0.76 | | 0.80 | | 0.76 | | 0.79 |
| | | | | | | |
Average cost of fuel, generated (in cents per net KWH) | 3.52 | | 2.21 | | 3.18 | | 2.18 |
Average cost of purchased power (in cents per net KWH)(*) | 8.22 | | 4.77 | | 6.58 | | 4.49 |
(*)Average cost of purchased power includes fuel purchased by Georgia Power for tolling agreements where power is generated by the provider.
Fuel
In the second quarter 2022, fuel expense was $628 million compared to $343 million for the corresponding period in 2021. The increase was primarily due to increases of 92.5% and 19.1% in the average cost per KWH generated by natural gas and coal, respectively, and an 11.1% increase in the volume of KWHs generated by coal.
For year-to-date 2022, fuel expense was $1.05 billion compared to $0.66 billion for the corresponding period in 2021. The increase was primarily due to increases of 65.6% and 17.6% in the average cost per KWH generated by natural gas and coal, respectively, and a 15.2% increase in the volume of KWHs generated by coal.
Purchased Power – Non-Affiliates
In the second quarter 2022, purchased power expense from non-affiliates was $246 million compared to $144 million for the corresponding period in 2021. For year-to-date 2022, purchased power expense from non-affiliates was $396 million compared to $288 million for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to increases of 73.9% and 32.7%, respectively, in the volume of KWHs purchased due to higher demand primarily driven by warmer weather in the second quarter 2022 and increases of 17.0% and 16.1%, respectively, in the average cost per KWH purchased primarily due to higher natural gas and coal prices.
Energy purchases from non-affiliates will vary depending on the market prices of wholesale energy as compared to the cost of the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation.
Purchased Power – Affiliates
In the second quarter 2022, purchased power expense from affiliates was $323 million compared to $149 million for the corresponding period in 2021. For year-to-date 2022, purchased power expense from affiliates was $529 million compared to $285 million for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to increases of 127.0% and 74.3%, respectively, in the average cost per KWH purchased primarily due to higher natural gas and coal prices. The increase for year-to-date 2022 was also due to an
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
increase of 9.9% 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
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $31 | | 5.7 | | $76 | | 7.5 |
In the second quarter 2022, other operations and maintenance expenses were $573 million compared to $542 million for the corresponding period in 2021. The increase was primarily due to increases of $14 million in transmission and distribution expenses primarily associated with line maintenance, $9 million associated with more unregulated energy conservation projects in 2022, $8 million in generation expenses primarily related to non-outage maintenance costs, $8 million in certain compensation and benefit expenses, $7 million in legal and regulatory expenses, and $4 million in amortization of cloud software, partially offset by a decrease of $16 million related to unregulated power delivery construction and maintenance projects.
For year-to-date 2022, other operations and maintenance expenses were $1.09 billion compared to $1.02 billion for the corresponding period in 2021. The increase was primarily due to increases of $49 million in transmission and distribution expenses primarily associated with line maintenance, $27 million in generation expenses primarily related to non-outage maintenance costs, $11 million in certain compensation and benefit expenses, $7 million in legal and regulatory expenses, and $5 million in amortization of cloud software, partially offset by a decrease of $26 million related to unregulated power delivery construction and maintenance projects and $17 million in gains from sales of integrated transmission system assets.
Depreciation and Amortization
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $14 | | 4.1 | | $26 | | 3.8 |
In the second quarter 2022, depreciation and amortization was $356 million compared to $342 million for the corresponding period in 2021. For year-to-date 2022, depreciation and amortization was $706 million compared to $680 million for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to additional plant in service and increases of $4 million and $6 million, respectively, in amortization of regulatory assets related to CCR AROs under the terms of the 2019 ARP. See Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Rate Plans – 2019 ARP" for additional information on recovery of CCR AROs.
Taxes Other Than Income Taxes
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $23 | | 19.5 | | $30 | | 12.8 |
In the second quarter 2022, taxes other than income taxes was $141 million compared to $118 million for the corresponding period in 2021. For year-to-date 2022, taxes other than income taxes was $265 million compared to $235 million for the corresponding period in 2021. The increases were primarily due to increases 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
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $(408) | | (88.7) | | $(456) | | (89.8) |
In the second quarter 2022 and 2021, Georgia Power recorded estimated probable losses on Plant Vogtle Units 3 and 4 of $52 million and $460 million, respectively. For year-to-date 2022 and 2021, Georgia Power recorded estimated probable losses on Plant Vogtle Units 3 and 4 totaling $52 million and $508 million, respectively. The losses reflect 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.
Interest Expense, Net of Amounts Capitalized
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $11 | | 10.4 | | $14 | | 6.7 |
In the second quarter 2022, interest expense, net of amounts capitalized was $117 million compared to $106 million for the corresponding period in 2021. For year-to-date 2022, interest expense, net of amounts capitalized was $224 million compared to $210 million for the corresponding period in 2021. The increases were primarily associated with higher average outstanding borrowings. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information on borrowings.
Other Income (Expense), Net
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $12 | | 28.6 | | $20 | | 24.1 |
In the second quarter 2022, other income (expense), net was $54 million compared to $42 million for the corresponding period in 2021. For year-to-date 2022, other income (expense), net was $103 million compared to $83 million for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to increases of $7 million and $10 million, respectively, in customer charges related to contributions in aid of construction and $4 million and $7 million, respectively, 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 (Benefit)
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $214 | | N/M | | $226 | | N/M |
N/M - Not meaningful
In the second quarter 2022, income tax expense was $164 million compared to income tax benefit of $50 million for the corresponding period in 2021. For year-to-date 2022, income tax expense was $194 million compared to income tax benefit of $32 million for the corresponding period in 2021. The increases were primarily due to a reduction in pre-tax earnings largely resulting from higher charges in the second quarter and year-to-date 2021 associated with the construction of Plant Vogtle Units 3 and 4 and an adjustment in the second quarter 2022 related to a prior year state tax credit carryforward. See Note (B) to the Condensed Financial Statements herein and Note 2 to the financial
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" and Note (G) to the Condensed Financial Statements herein for additional information.
Mississippi Power
Net Income
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $7 | | 18.4 | | $4 | | 4.8 |
Mississippi Power's net income in the second quarter 2022 was $45 million compared to $38 million for the corresponding period in 2021. For year-to-date 2022, net income was $87 million compared to $83 million for the corresponding period in 2021. The increases were primarily due to an increase in revenues, partially offset by an increase in operations and maintenance expenses. The year-to-date increase was also partially offset by an increase in income taxes.
Retail Revenues
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $33 | | 15.1 | | $47 | | 11.1 |
In the second quarter 2022, retail revenues were $252 million compared to $219 million for the corresponding period in 2021. For year-to-date 2022, retail revenues were $469 million compared to $422 million for the corresponding period in 2021.
Details of the changes in retail revenues were as follows:
| | | | | | | | | | | | | | | | | | | | | | | |
| | Second Quarter 2022 | | Year-To-Date 2022 |
| | (in millions) | | (% change) | | (in millions) | | (% change) |
| Retail – prior year | $ | 219 | | | | | $ | 422 | | | |
| Estimated change resulting from – | | | | | | | |
| Rates and pricing | 2 | | | 0.9 | % | | 5 | | | 1.2 | % |
| Sales growth | 2 | | | 0.9 | | | 4 | | | 0.9 | |
| Weather | 9 | | | 4.1 | | | 7 | | | 1.7 | |
| Fuel and other cost recovery | 20 | | | 9.1 | | | 31 | | | 7.3 | |
| Retail – current year | $ | 252 | | | 15.0 | % | | $ | 469 | | | 11.1 | % |
Revenues associated with changes in rates and pricing increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021 primarily due to new PEP rates that became effective for the first billing cycle of April 2022, partially offset by a decrease in revenues associated with a tolling arrangement. 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 second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. Weather-adjusted residential KWH sales decreased 0.4% in the second quarter 2022 when compared to the corresponding period in 2021 due to a decrease in customer usage. Weather-adjusted residential KWH sales increased 0.2% for year-to-date 2022 when compared to the corresponding period in 2021 due to customer growth. Weather-adjusted commercial KWH sales increased 1.2% and 2.0% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 due to customer growth. Industrial KWH sales increased 3.4% and 1.8% in the second quarter and year-to-date 2022, respectively, when
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
compared to the corresponding periods in 2021 primarily due to increases in the petroleum, pipeline, and transportation sectors.
Fuel and other cost recovery revenues increased in the second quarter and year-to-date 2022 when compared to the corresponding periods 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. See Note 2 to the financial statements in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein under "Mississippi Power" for additional information.
Wholesale Revenues – Non-Affiliates
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $9 | | 16.7 | | $14 | | 12.0 |
In the second quarter 2022, wholesale revenues from sales to non-affiliates were $63 million compared to $54 million for the corresponding period in 2021. For year-to-date 2022, wholesale revenues from sales to non-affiliates were $131 million compared to $117 million for the corresponding period in 2021. The increases were primarily due to higher fuel costs and an increase in base revenue from MRA customers primarily due to warmer weather in 2022.
Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of 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 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. See Note (B) to the Condensed Financial Statements under "Mississippi Power – Municipal and Rural Associations Tariff" herein for additional information.
Wholesale Revenues – Affiliates
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $82 | | N/M | | $92 | | N/M |
N/M - Not meaningful
In the second quarter 2022, wholesale revenues from sales to affiliates were $107 million compared to $25 million for the corresponding period in 2021. The increase was primarily due to increases of $69 million associated with higher fuel prices, primarily driven by natural gas, and $13 million associated with higher KWH sales due to lower cost resources as compared to the available affiliate company generation.
For year-to-date 2022, wholesale revenues from sales to affiliates were $149 million compared to $57 million for the corresponding period in 2021. The increase was primarily due to increases of $84 million associated with higher fuel prices, primarily driven by natural gas, and $7 million associated with higher KWH sales due to lower cost resources as compared to the available affiliate company generation.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
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.
Other Revenues
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $7 | | N/M | | $6 | | 42.9 |
N/M - Not meaningful
In the second quarter 2022, other revenues were $12 million compared to $5 million for the corresponding period in 2021. For year-to-date 2022, other revenues were $20 million compared to $14 million for the corresponding period in 2021. The increases were primarily due to a $5 million increase in unregulated sales associated with power delivery construction and maintenance projects and outdoor lighting.
Fuel and Purchased Power Expenses
| | | | | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-to-Date 2022 vs. Year-to-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| Fuel | $ | 105 | | | 116.0 | | $ | 130 | | | 67.9 |
| Purchased power | — | | | 1.9 | | 1 | | | 6.8 |
| Total fuel and purchased power expenses | $ | 105 | | | | | $ | 131 | | | |
In the second quarter 2022, total fuel and purchased power expenses were $207 million compared to $102 million for the corresponding period in 2021. The increase was due to a $92 million increase in the average cost of fuel and purchased power and a $13 million net increase associated with the volume of KWHs generated and purchased.
For year-to-date 2022, total fuel and purchased power expenses were $339 million compared to $208 million for the corresponding period in 2021. The increase was primarily due to a $126 million increase in the average cost of fuel and purchased power and a $5 million net increase 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:
| | | | | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 | | Second Quarter 2021 | | Year-To-Date 2022 | | Year-To-Date 2021 |
Total generation (in millions of KWHs) | 4,483 | | 3,813 | | 8,557 | | 8,137 |
Total purchased power (in millions of KWHs) | 166 | | 317 | | 286 | | 438 |
Sources of generation (percent) – | | | | | | | |
| Gas | 88 | | 91 | | 90 | | 91 |
| Coal | 12 | | 9 | | 10 | | 9 |
Cost of fuel, generated (in cents per net KWH) – | | | | | | | |
| Gas | 4.73 | | 2.50 | | 4.04 | | 2.45 |
| Coal | 3.95 | | 3.06 | | 3.86 | | 3.12 |
Average cost of fuel, generated (in cents per net KWH) | 4.63 | | 2.56 | | 4.02 | | 2.52 |
Average cost of purchased power (in cents per net KWH) | 6.57 | | 3.38 | | 5.72 | | 3.57 |
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Fuel
In the second quarter 2022, fuel expense was $196 million compared to $91 million for the corresponding period in 2021. The increase was due to an 89.2% increase in the average cost of natural gas per KWH generated, a 29.1% increase in the average cost of coal per KWHs generated, a 52.1% increase in the volume of KWHs generated by coal, and a 16.0% increase in the volume of KWHs generated by natural gas.
For year-to-date 2022, fuel expense was $322 million compared to $192 million for the corresponding period in 2021. The increase was due to a 64.9% increase in the average cost of natural gas per KWH generated, a 23.7% increase in the average cost of coal per KWHs generated, a 15.5% increase in the volume of KWHs generated by coal, and a 4.2% increase in the volume of KWHs generated by natural gas.
Other Operations and Maintenance Expenses
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $15 | | 19.7 | | $23 | | 16.0 |
In the second quarter 2022, other operations and maintenance expenses were $91 million compared to $76 million for the corresponding period in 2021. The increase was due to increases of $5 million related to unregulated construction and maintenance contracts, $3 million associated with storm reserve accruals, and $3 million in transmission and distribution expenses primarily associated with line maintenance.
For year-to-date 2022, other operations and maintenance expenses were $167 million compared to $144 million for the corresponding period in 2021. The increase was primarily due to increases of $6 million in transmission and distribution expenses primarily associated with line maintenance, $5 million related to unregulated construction and maintenance contracts, $4 million associated with storm reserve accruals, and $4 million associated with the Kemper County energy facility (primarily related to lower salvage proceeds in 2022 as compared to 2021).
See Note 2 to the financial statements in Item 8 of the Form 10-K under "Mississippi Power – System Restoration Rider" for additional information on storm reserve accruals.
Income Taxes
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $4 | | 50.0 | | $8 | | 66.7 |
For year-to-date 2022, income taxes were $20 million compared to $12 million for the corresponding period in 2021. A reduction in the flowback of excess deferred income taxes associated with new PEP rates that became effective in April 2022 contributed $5 million to the increase, which also reflects $3 million due to higher pre-tax earnings. 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 Power
Net Income Attributable to Southern Power
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $62 | | 172.2 | | $37 | | 27.8 |
Net income attributable to Southern Power in the second quarter 2022 was $98 million compared to $36 million for the corresponding period in 2021. Net income attributable to Southern Power for year-to-date 2022 was $170 million compared to $133 million for the corresponding period in 2021.The increases were primarily due to higher revenues driven by higher market prices of energy and new natural gas PPAs, as well as higher HLBV income associated with tax equity partnerships. The year-to-date increase was partially offset by gains from the contributions of wind turbine equipment to various equity method investments in the first quarter 2021.
Operating Revenues
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $409 | | 83.5 | | $508 | | 54.6 |
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.
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.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Operating Revenues Details
Details of Southern Power's operating revenues were as follows:
| | | | | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 | | Second Quarter 2021 | | Year-To-Date 2022 | | Year-To-Date 2021 |
| (in millions) |
| PPA capacity revenues | $ | 109 | | | $ | 96 | | | $ | 214 | | | $ | 192 | |
| PPA energy revenues | 579 | | | 296 | | | 921 | | | 541 | |
| Total PPA revenues | 688 | | | 392 | | | 1,135 | | | 733 | |
| Non-PPA revenues | 202 | | | 93 | | | 286 | | | 188 | |
| Other revenues | 9 | | | 5 | | | 17 | | | 9 | |
| Total operating revenues | $ | 899 | | | $ | 490 | | | $ | 1,438 | | | $ | 930 | |
In the second quarter 2022, total operating revenues were $899 million, reflecting a $409 million, or 83%, increase from the corresponding period in 2021. The increase in operating revenues was primarily due to the following:
•PPA capacity revenues increased $13 million, or 14%, 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 $283 million, or 96%, primarily due to a $212 million increase in sales under existing natural gas PPAs resulting from a $171 million increase in the price of fuel and purchased power and a $41 million increase in the volume of KWHs sold. Also contributing to the increase was a $77 million increase in sales associated with new natural gas PPAs.
•Non-PPA revenues increased $109 million, or 117%, primarily due to a $124 million increase in the market price of energy, partially offset by a $16 million decrease in the volume of KWHs sold through short-term sales.
For year-to-date 2022, total operating revenues were $1.4 billion, reflecting a $508 million, or 55%, increase from the corresponding period in 2021. The increase in operating revenues was primarily due to the following:
•PPA capacity revenues increased $22 million, or 11%, 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 $380 million, or 70%, primarily due to a $271 million increase in sales under existing natural gas PPAs resulting from a $207 million increase in the price of fuel and purchased power and a $64 million increase in the volume of KWHs sold. Also contributing to the increase was a $124 million increase in sales associated with new natural gas PPAs, partially offset by a $17 million decrease due to the contractual expiration of natural gas PPAs.
•Non-PPA revenues increased $98 million, or 52%, primarily due to a $129 million increase in the market price of energy, partially offset by a $29 million decrease in the volume of KWHs sold through short-term sales.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Fuel and Purchased Power Expenses
Details of Southern Power's generation and purchased power were as follows:
| | | | | | | | | | | | | | | | | |
| | Second Quarter 2022 | Second Quarter 2021 | | Year-To-Date 2022 | Year-To-Date 2021 |
| (in billions of KWHs) |
| Generation | 12.8 | 10.3 | | 23.9 | 19.7 |
| Purchased power | 0.7 | 0.7 | | 1.1 | 1.3 |
| Total generation and purchased power | 13.5 | 11.0 | | 25.0 | 21.0 |
| | | | | |
Total generation and purchased power (excluding solar, wind, fuel cells, and tolling agreements) | 7.5 | 6.3 | | 14.4 | 12.4 |
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:
| | | | | | | | | | | | | | | | | | | | | | | |
| | Second Quarter 2022 vs. Second Quarter 2021 | | Year-to-Date 2022 vs. Year-to-Date 2021 |
| | (change in millions) | | (% change) | | (change in millions) | | (% change) |
| Fuel | $ | 297 | | | 212.1 | | $ | 388 | | | 138.1 |
| Purchased power | 43 | | | 172.0 | | 43 | | | 93.5 |
| Total fuel and purchased power expenses | $ | 340 | | | | | $ | 431 | | | |
In the second quarter 2022, total fuel and purchased power expenses increased $340 million, or 206%, compared to the corresponding period in 2021. Fuel expense increased $297 million due to a $266 million increase associated with the average cost of fuel and a $31 million increase associated with the volume of KWHs generated. Purchased power expense increased $43 million primarily due to an increase in the average cost of purchased power.
For year-to-date 2022, total fuel and purchased power expenses increased $431 million, or 132%, compared to the corresponding period in 2021. Fuel expense increased $388 million due to a $333 million increase associated with the average cost of fuel and a $55 million increase associated with the volume of KWHs generated. Purchased power expense increased $43 million primarily due to an increase in the average cost of purchased power.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Gain on Dispositions, Net
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $— | | — | | $(37) | | (94.9) |
For year-to-date 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.
Income Taxes (Benefit)
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $27 | | N/M | | $24 | | N/M |
N/M - Not meaningful
In the second quarter 2022, income tax expense was $25 million compared to a benefit of $2 million for the corresponding period in 2021. The change was primarily due to higher pre-tax earnings, partially offset by higher wind PTCs.
For year-to-date 2022, income tax expense was $13 million compared to a benefit of $11 million for the corresponding period in 2021. The change was primarily due to higher pre-tax earnings for year-to-date 2022 and a change in state apportionment methodology resulting from tax legislation enacted by the State of Alabama in the first quarter 2021, partially offset by higher wind PTCs for year-to-date 2022.
Net Loss Attributable to Noncontrolling Interests
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $22 | | N/M | | $34 | | 103.0 |
N/M - Not meaningful
In the second quarter 2022, net loss attributable to noncontrolling interests was $22 million compared to an immaterial loss for the corresponding period in 2021. For year-to-date 2022, net loss attributable to noncontrolling interests was $67 million compared to $33 million for the corresponding period in 2021. The increased losses attributable to noncontrolling interests were primarily due to higher HLBV loss allocations to tax equity partners, partially offset by higher income allocations to equity partners.
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.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
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
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $180 | | N/M | | $100 | | 30.0 |
N/M - Not meaningful
In the second quarter 2022, net income was $115 million compared to a net loss of $65 million for the corresponding period in 2021. The second quarter 2021 results include $112 million of net loss from Sequent, which was sold on July 1, 2021. Net income increased $59 million at gas pipeline investments primarily as a result of a 2021 impairment charge related to the PennEast pipeline project and $12 million at gas distribution operations primarily due to base rate increases and continued investment in infrastructure replacement.
For year-to-date 2022, net income was $433 million compared to $333 million for the corresponding period in 2021. Net income increased $59 million at gas pipeline investments as a result of a 2021 impairment charge related to the PennEast pipeline project, $43 million at gas distribution operations primarily due to base rate increases and continued investment in infrastructure replacement, and $5 million at gas marketing services primarily related to higher commodity prices and higher sales to commercial customers. The year-to-date 2021 results also included $14 million of net income from Sequent, which was sold on July 1, 2021.
See Notes 2, 7, 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
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $406 | | 60.0 | | $769 | | 32.4 |
In the second quarter 2022, natural gas revenues, including alternative revenue programs, were $1.1 billion compared to $677 million for the corresponding period in 2021. For year-to-date 2022, natural gas revenues, including alternative revenue programs, were $3.1 billion compared to $2.4 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:
| | | | | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 | | Year-To-Date 2022 |
| (in millions) | | (% change) | | (in millions) | | (% change) |
| Natural gas revenues – prior year | $ | 677 | | | | | $ | 2,371 | | | |
| Estimated change resulting from – | | | | | | | |
| Infrastructure replacement programs and base rate changes | 46 | | | 6.8 | % | | 132 | | | 5.6 | % |
| Gas costs and other cost recovery | 239 | | | 35.3 | | | 783 | | | 33.0 | |
| Gas marketing services | (5) | | | (0.7) | | | 13 | | | 0.5 | |
| Wholesale gas services | 110 | | | 16.2 | | | (187) | | | (7.9) | |
| | | | | | | |
| Other | 16 | | | 2.4 | | | 28 | | | 1.2 | |
| Natural gas revenues – current year | $ | 1,083 | | | 60.0 | % | | $ | 3,140 | | | 32.4 | % |
Revenues from infrastructure replacement programs and base rate changes increased in the second quarter and year-to-date 2022 compared to the corresponding periods in 2021 primarily due to rate increases at Nicor Gas, 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 second quarter and year-to-date 2022 compared to the corresponding periods 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 decreased in the second quarter 2022 compared to the corresponding period in 2021 due to unrealized hedge losses and warmer weather in the second quarter 2022. Revenues from gas marketing services increased for year-to-date 2022 compared to the corresponding period in 2021 due to higher commodity prices and higher sales to commercial customers.
The changes in revenues related to wholesale gas services were 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.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Second Quarter | | 2022 vs. normal | 2022 vs. 2021 | | Year-to-Date | | 2022 vs. normal | 2022 vs. 2021 |
| Normal(*) | 2022 | 2021 | | (warmer) | (warmer) | | Normal(*) | 2022 | 2021 | | colder (warmer) | colder (warmer) |
| (in thousands) | | | | | (in thousands) | | | |
| Illinois | 645 | | 620 | | 634 | | | (3.9) | % | (2.2) | % | | 3,644 | | 3,627 | | 3,580 | | | (0.5) | % | 1.3 | % |
| Georgia | 126 | | 110 | | 142 | | | (12.7) | % | (22.5) | % | | 1,428 | | 1,361 | | 1,396 | | | (4.7) | % | (2.5) | % |
(*)Normal represents the 10-year average from January 1, 2012 through June 30, 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.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
The following table provides the number of customers served by Southern Company Gas at June 30, 2022 and 2021:
| | | | | | | | | | | | | | | | | |
| June 30, | | |
| 2022 | | 2021 | | 2022 vs. 2021 |
| (in thousands, except market share %) | | (% change) |
| Gas distribution operations | 4,314 | | | 4,300 | | | 0.3 | % |
| Gas marketing services | | | | | |
Energy customers(*) | 610 | | | 612 | | | (0.3) | % |
| Market share of energy customers in Georgia | 28.6 | % | | 29.1 | % | | |
| | | | | |
| | | | | |
(*)Gas marketing services' customers are primarily located in Georgia and Illinois.
Southern Company Gas anticipates customer growth and uses a variety of targeted marketing programs to attract new customers and to retain existing customers.
Cost of Natural Gas
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $221 | | 95.7 | | $732 | | 89.9 |
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 88% and 89% of the total cost of natural gas in the second quarter and year-to-date 2022, respectively. 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 second quarter 2022, cost of natural gas was $452 million compared to $231 million for the corresponding period in 2021. For year-to-date 2022, cost of natural gas was $1.5 billion compared to $814 million for the corresponding period in 2021. The increases reflect higher gas cost recovery as a result of increases of 153.2% and 119.4% in natural gas prices in the second quarter and year-to-date 2022, respectively, compared to the corresponding periods 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.
| | | | | | | | | | | | | | | | | | | | | | | |
| Second Quarter | 2022 vs. 2021 | | Year-to-Date | 2022 vs. 2021 |
| 2022 | 2021 | | 2022 | 2021 |
Gas distribution operations (mmBtu in millions) | | | | | | |
| Firm | 111 | | 103 | | 7.8 | % | | 415 | | 391 | | 6.1 | % |
| Interruptible | 22 | | 23 | | (4.3) | | | 47 | | 50 | | (6.0) | |
| Total | 133 | | 126 | | 5.6 | % | | 462 | | 441 | | 4.8 | % |
Wholesale gas services (mmBtu in millions/day) | | | | | | |
Daily physical sales(*) | — | | 6.1 | | (100.0) | % | | — | | 6.6 | | (100.0) | % |
Gas marketing services (mmBtu in millions) | | | | | | |
| Firm: | | | | | | | |
| Georgia | 5 | | 4 | | 25.0 | % | | 21 | | 23 | | (8.7) | % |
| Illinois | 1 | | 1 | | — | | | 4 | | 5 | | (20.0) | |
| | | | | | | |
| Other | 3 | | 2 | | 50.0 | | | 7 | | 8 | | (12.5) | |
| Interruptible large commercial and industrial | 3 | | 3 | | — | | | 7 | | 7 | | — | |
| Total | 12 | | 10 | | 20.0 | % | | 39 | | 43 | | (9.3) | % |
(*)As a result of the sale of Sequent, wholesale gas services had no sales in the second quarter and year-to-date 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
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $33 | | 14.2 | | $38 | | 7.1 |
In the second quarter 2022, other operations and maintenance expenses were $266 million compared to $233 million for the corresponding period in 2021. Other operations and maintenance expenses increased approximately $37 million excluding expenses related to Sequent in the second quarter 2021. The increase was primarily due to higher compensation and benefit expenses and higher expenses passed through directly to customers primarily related to bad debt at gas distribution operations.
For year-to-date 2022, other operations and maintenance expenses were $570 million compared to $532 million for the corresponding period in 2021. Excluding $53 million of expenses related to Sequent for year-to-date 2021, other operations and maintenance expenses increased approximately $91 million. The increase was primarily due to increases of $33 million in compensation and benefit expenses, $24 million in expenses passed through directly to customers primarily related to bad debt at gas distribution operations, $16 million in technology-related costs, $8 million in customer accounts expenses, and $7 million in expenses primarily related to higher fuel costs.
Depreciation and Amortization
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $5 | | 3.8 | | $12 | | 4.6 |
For year-to-date 2022, depreciation and amortization was $275 million compared to $263 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
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $13 | | 26.5 | | $33 | | 25.4 |
In the second quarter 2022, taxes other than income taxes were $62 million compared to $49 million for the corresponding period in 2021. For year-to-date 2022, taxes other than income taxes were $163 million compared to $130 million for the corresponding period in 2021. The increases primarily reflect 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.
Earnings (Loss) from Equity Method Investments
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $83 | | 159.6 | | $82 | | N/M |
N/M - Not meaningful
In the second quarter 2022, earnings from equity method investments were $31 million compared to a loss of $52 million for the corresponding period in 2021. For year-to-date 2022, earnings from equity method investments were $71 million compared to a loss of $11 million for the corresponding period in 2021. The changes were primarily due to a pre-tax impairment charge of $82 million recorded in the second quarter 2021 related to the PennEast Pipeline project. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (E) to the Condensed Financial Statements herein under "Southern Company Gas" for additional information.
Other Income (Expense), Net
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $30 | | 214.3 | | $110 | | 141.0 |
In the second quarter 2022, other income (expense), net was $16 million of income compared to $14 million of expense for the corresponding period in 2021. For year-to-date 2022, other income (expense), net was $32 million of income compared to $78 million of expense for the corresponding period in 2021. The changes were largely due to charitable contributions of $26 million and $101 million in the second quarter and year-to-date 2021, respectively.
Income Taxes (Benefit)
| | | | | | | | | | | | | | | | | | | | |
| Second Quarter 2022 vs. Second Quarter 2021 | | Year-To-Date 2022 vs. Year-To-Date 2021 |
| (change in millions) | | (% change) | | (change in millions) | | (% change) |
| $65 | | 224.1 | | $42 | | 45.7 |
In the second quarter 2022, income tax expense was $36 million compared to income tax benefit of $29 million for the corresponding period in 2021. The change was primarily due to the pre-tax impairment charge at gas pipeline investments in 2021 related to the PennEast Pipeline project, a pre-tax loss at wholesale gas services in the second quarter 2021, and higher pre-tax earnings primarily at gas distribution operations.
For year-to-date 2022, income taxes were $134 million compared to $92 million for the corresponding period in 2021. The increase was primarily due to the pre-tax impairment charge at gas pipeline investments in 2021 related to the PennEast Pipeline project and higher pre-tax earnings primarily at gas distribution operations.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information on the impairment charge related to the PennEast Pipeline project.
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.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | 2022 | | 2021 |
| Operating Revenues | | Operating Expenses | | Net Income (Loss) | | Operating Revenues | | Operating Expenses | | Net Income (Loss) |
| (in millions) | | (in millions) |
| Second Quarter |
| Gas distribution operations | $ | 980 | | | $ | 819 | | | $ | 92 | | | $ | 710 | | | $ | 564 | | | $ | 80 | |
| Gas pipeline investments | 8 | | | 2 | | | 23 | | | 8 | | | 3 | | | (36) | |
Wholesale gas services(*) | — | | | — | | | — | | | (110) | | | 11 | | | (112) | |
| Gas marketing services | 92 | | | 90 | | | 1 | | | 64 | | | 54 | | | 6 | |
| All other | 10 | | | 14 | | | (1) | | | 11 | | | 20 | | | (3) | |
| Intercompany eliminations | (7) | | | (7) | | | — | | | (6) | | | (6) | | | — | |
| Consolidated | $ | 1,083 | | | $ | 918 | | | $ | 115 | | | $ | 677 | | | $ | 646 | | | $ | (65) | |
| | | | | | | | | | | |
| Year-to-Date |
| Gas distribution operations | $ | 2,782 | | | $ | 2,293 | | | $ | 306 | | | $ | 1,910 | | | $ | 1,477 | | | $ | 263 | |
| Gas pipeline investments | 16 | | | 5 | | | 52 | | | 16 | | | 6 | | | (7) | |
Wholesale gas services(*) | — | | | — | | | — | | | 188 | | | 67 | | | 14 | |
| Gas marketing services | 335 | | | 240 | | | 67 | | | 259 | | | 174 | | | 62 | |
| All other | 26 | | | 35 | | | 8 | | | 18 | | | 35 | | | 1 | |
| Intercompany eliminations | (19) | | | (19) | | | — | | | (20) | | | (20) | | | — | |
| Consolidated | $ | 3,140 | | | $ | 2,554 | | | $ | 433 | | | $ | 2,371 | | | $ | 1,739 | | | $ | 333 | |
(*)As a result of the sale of Sequent, wholesale gas services is no longer a reportable segment for the second quarter and year-to-date 2022. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.
Gas Distribution Operations
Gas distribution operations is the largest component of Southern Company Gas' business and is subject to regulation and oversight by 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.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
In the second quarter and year-to-date 2022, net income increased $12 million, or 15.0%, and $43 million, or 16.3%, respectively, when compared to the corresponding periods in 2021, as described further below:
•Operating revenues increased $270 million and $872 million, respectively, when compared to the corresponding periods in 2021 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 $255 million and $816 million, respectively, when compared to the corresponding periods in 2021 primarily due to increases of $195 million and $673 million, respectively, in the cost of gas as a result of higher natural gas prices and higher volumes sold compared to 2021, higher compensation expenses, and higher 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.
•Other income and (expense) increased $4 million and $9 million, respectively, when compared to the corresponding periods in 2021, primarily due to an increase in non-service cost-related retirement benefits income. See Note (H) to the Condensed Financial Statements herein for additional information.
•Interest expense, net of amounts capitalized increased $3 million and $6 million, respectively, when compared to the corresponding periods in 2021 primarily due to additional debt issued to finance continued investments. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information on borrowings.
•Income taxes increased $4 million and $16 million, respectively, when compared to the corresponding periods in 2021 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.
Net income increased $59 million for both the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. The increases were primarily due to a pre-tax impairment charge of $82 million ($58 million after tax) in the second quarter 2021 related to the equity method investment in the PennEast Pipeline project. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.
Gas Marketing Services
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 second quarter 2022, net income decreased $5 million, or 83.3%, when compared to the corresponding period in 2021. The decrease was primarily due to an increase of $36 million in operating expenses primarily due to $32 million in higher cost of gas, largely offset by a related increase of $28 million in operating revenues.
For year-to-date 2022, net income increased $5 million, or 8.1%, when compared to the corresponding period in 2021. The increase was primarily due to a $76 million increase in operating revenues as a result of higher commodity prices and higher sales to commercial customers, partially offset by a $66 million increase in operating expenses primarily due to higher cost of natural gas and an increase of $5 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.
For year-to-date 2022, net income increased $7 million when compared to the corresponding period in 2021. Operating revenues increased $8 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.
FUTURE EARNINGS POTENTIAL
Each Registrant's results of operations are not necessarily indicative of its future earnings potential. The level of the Registrants' future earnings depends on numerous factors that affect the opportunities, challenges, and risks of the Registrants' primary businesses of selling electricity and/or distributing natural gas, as described further herein.
For the traditional electric operating companies, these factors include the ability to maintain constructive regulatory environments that allow for the timely recovery of prudently-incurred costs during a time of increasing costs, including those related to projected long-term demand growth, stringent environmental standards, including CCR rules, safety, system reliability and resiliency, fuel, restoration following major storms, and capital expenditures, including constructing new electric generating plants and expanding and improving the transmission and distribution systems; continued customer growth; and the trends of higher inflation and reduced electricity usage per customer, especially in residential and commercial markets. For Georgia Power, 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. The drivers, speed, and depth of the 2020 economic contraction were unprecedented and continue to reduce energy demand across the Southern Company system's service territory, primarily in the commercial class. Retail electric revenues attributable to changes in sales increased in the first half of 2022 when compared to the corresponding period in 2021 primarily due to the normalization of economic activity; however, total retail electric sales for the Southern Company system continued to be negatively impacted by the COVID-19 pandemic when compared to pre-pandemic trends. 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. Based on these factors, the probability of the U.S. economy falling into a recession has heightened. The impacts of new COVID-19 variants, responses to the COVID-19 pandemic by both customers and governments, ongoing geopolitical threats, such as the escalation of the Russia-Ukraine war, and the potential of future COVID-19-related lockdowns in Asian markets or elsewhere could further disrupt global supply chains and increase the severity of a possible economic downturn in the Southern Company system's service territory. 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 half of 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 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
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
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. 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, impacted by heightened inflation caused by unprecedented shocks to the broader economy, 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)
Environmental Laws and Regulations
Coal Combustion Residuals
On July 20, 2022, Mobile Baykeeper, through its counsel Southern Environmental Law Center, released an advance notice of intent to sue Alabama Power for alleged violations of the Resource Conservation and Recovery Act (RCRA) and regulations governing CCR. Mobile Baykeeper claims that Alabama Power's plan to close the Plant Barry ash pond under the closure-in-place methodology violates regulations governing CCR and the RCRA. Under the RCRA, Mobile Baykeeper is required to give Alabama Power advance notice of intent at least 60 days before filing suit. See Note 6 to the financial statements in Item 8 of the Form 10-K for a discussion of Alabama Power's ARO liabilities related to facilities that are subject to the CCR Rule and the related state rule. The ultimate outcome of this matter cannot be determined at this time.
Global Climate Issues
On June 30, 2022, the U.S. Supreme Court issued an opinion limiting the EPA's authority to regulate greenhouse gas emissions under the Clean Air Act. The Court's review in the case focused on whether the EPA's authority under the Clean Air Act allows the EPA to regulate the electric industry in a manner as broad as the Clean Power Plan (CPP), which was repealed and replaced by the Affordable Clean Energy rule (ACE Rule). The Court held that the generation shifting to lower carbon emitting sources approach in the CPP is not authorized by the Clean Air Act. However, the Court did not decide whether the EPA may adopt measures only applied at the individual electric generating source, which is the basis for the ACE Rule. The EPA has announced its intent to propose a rule for existing power plants pursuant to the Clean Air Act by March 2023. The ultimate impact of the Court's decision cannot be determined at this time.
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
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
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.
Application of Critical Accounting Policies and Estimates
The Registrants prepare their financial statements in accordance with GAAP. Significant accounting policies are described in the notes to the financial statements in 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.
Estimated Cost, Schedule, and Rate Recovery for the Construction of Plant Vogtle Units 3 and 4
(Southern Company and Georgia Power)
As of June 30, 2022, Georgia Power revised its total project capital cost forecast to $10.5 billion (net of $1.7 billion received under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds). This forecast includes construction contingency of $60 million and is based on projected in-service dates at the end of the first quarter 2023 and the fourth quarter 2023 for Units 3 and 4, respectively.
The projected schedule for Unit 3 primarily depends on 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. Unit 4's projected schedule primarily depends on Unit 3 progress through fuel load, startup, and testing; overall construction productivity and production levels improving, particularly in electrical installation, including terminations; and appropriate levels of craft laborers, particularly electricians and pipefitters, being added and maintained. Any further delays could result in later in-service dates and cost increases.
During the first half of 2022, established construction contingency totaling $126 million was assigned to the base capital cost forecast for costs primarily associated with construction productivity, the pace of system turnovers, additional craft and support resources, and procurement for Units 3 and 4. Georgia Power also increased its total project capital cost forecast as of June 30, 2022 and recorded a pre-tax charge of $36 million ($27 million after tax) to replenish construction contingency.
Georgia Power and the other Vogtle Owners do not agree on either the starting dollar amount for the determination of cost increases subject to the cost-sharing and tender provisions of the Global Amendments (as defined in Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction – Joint Owner Contracts"
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
herein) or the extent to which COVID-19-related costs impact those provisions. Georgia Power recorded an additional pre-tax charge to income in the second quarter 2022 of approximately $16 million ($12 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 $480 million associated with these provisions based on the current project capital cost forecast. In October 2021, Georgia Power and the other Vogtle Owners entered into an agreement, which was modified on June 3, 2022, to clarify the process for the tender provisions of the Global Amendments to provide for a decision between 120 and 194 days after the tender option is triggered, which the other Vogtle Owners assert occurred on February 14, 2022, and would require the other Vogtle Owners to notify Georgia Power of their intent to exercise their tender options by August 27, 2022. On June 17, 2022 and July 26, 2022, OPC and Dalton, respectively, notified Georgia Power of their purported exercises of their tender options.
The ultimate outcome of these matters cannot be determined at this time. However, any extension of the in-service date beyond the first quarter 2023 for Unit 3 or the fourth quarter 2023 for Unit 4, including the current level of cost sharing described in Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein, is estimated to result in additional base capital costs for Georgia Power of up to $35 million per month for Unit 3 and $45 million per month for Unit 4, as well as the related AFUDC and any additional related construction, support resources, or testing costs. See Note 2 to the financial statements in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein under "Georgia Power – Nuclear Construction" for additional information.
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 June 30, 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 second quarter 2022, the market price of Southern Company's common stock was $71.31 per share (based on the closing price as reported on the NYSE) and the book value was $27.03 per share, representing a market-to-book ratio of 264%, compared to $68.58, $26.30, and 261%, respectively, at the end of 2021. Southern Company's common stock dividend for the second quarter 2022 was $0.68 per share compared to $0.66 per share in the second 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
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
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.
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 on August 1, 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 in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements herein under "Equity Units" 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). During the six months ended June 30, 2022, Southern Power utilized tax credits, which provided $239 million in operating cash flows.
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 half of 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 June 30, 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.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Certain Registrants' current liabilities frequently exceed their current assets because of long-term debt maturities and the periodic use of short-term debt as a funding source, as well as significant seasonal fluctuations in cash needs. The Registrants generally plan to refinance long-term debt as it matures. The following table shows the amount by which current liabilities exceeded current assets at June 30, 2022 for the applicable Registrants:
| | | | | | | | | | | | | | | | | | |
| At June 30, 2022 | Southern Company | | Georgia
Power | Mississippi Power | Southern Power | Southern Company Gas |
| (in millions) |
| Current liabilities in excess of current assets | $ | 1,706 | | | $ | 1,036 | | $ | 15 | | $ | 1 | | $ | 105 | |
The Registrants believe the need for working capital can be adequately met by utilizing operating cash flows, as well as commercial paper, lines of credit, and short-term bank notes, as market conditions permit. In addition, under certain circumstances, the Subsidiary Registrants may utilize equity contributions and/or loans from Southern Company.
Bank Credit Arrangements
At June 30, 2022, the Registrants' unused committed credit arrangements with banks were as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| At June 30, 2022 | Southern
Company
parent | Alabama Power | Georgia
Power | Mississippi Power | Southern Power(a) | Southern Company Gas(b) | SEGCO | Southern
Company |
| (in millions) |
| Unused committed credit | $ | 1,998 | | $ | 1,250 | | $ | 1,726 | | $ | 275 | | $ | 568 | | $ | 1,748 | | $ | 30 | | $ | 7,595 | |
(a)At June 30, 2022, Southern Power also had two continuing letters of credit facilities for standby letters of credit, of which $16 million was unused. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.
(b)Includes $798 million and $950 million at Southern Company Gas Capital and Nicor Gas, respectively.
Subject to applicable market conditions, the Registrants, Nicor Gas, and SEGCO expect to renew or replace their bank credit arrangements as needed, prior to expiration. In connection therewith, the Registrants, Nicor Gas, and SEGCO may extend the maturity dates and/or increase or decrease the lending commitments thereunder.
A portion of the unused credit with banks is allocated to provide liquidity support to the revenue bonds of the traditional electric operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity support at June 30, 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 June 30, 2022, Georgia Power had approximately $445 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:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Short-term Debt at June 30, 2022 | | Short-term Debt During the Period(*) |
| | Amount
Outstanding | | Weighted
Average
Interest
Rate | | Average
Amount
Outstanding | | Weighted
Average
Interest
Rate | | Maximum
Amount
Outstanding |
| | (in millions) | | | | (in millions) | | | | (in millions) |
| Southern Company | $ | 2,510 | | | 2.0 | % | | $ | 2,061 | | | 1.2 | % | | $ | 2,588 | |
| Alabama Power | — | | | — | | | 10 | | | 0.8 | | | 100 | |
| Georgia Power | 400 | | | 1.8 | | | 551 | | | 1.1 | | | 916 | |
| Mississippi Power | 16 | | | 2.1 | | | 21 | | | 2.0 | | | 35 | |
| Southern Power | 306 | | | 1.9 | | | 115 | | | 1.3 | | | 350 | |
| Southern Company Gas: | | | | | | | | | |
| Southern Company Gas Capital | $ | 316 | | | 2.0 | % | | $ | 314 | | | 1.2 | % | | $ | 446 | |
| Nicor Gas | 200 | | | 2.1 | | | 203 | | | 1.2 | | | 273 | |
| Southern Company Gas Total | $ | 516 | | | 2.0 | % | | $ | 517 | | | 1.2 | % | | |
(*)Average and maximum amounts are based upon daily balances during the three-month period ended June 30, 2022.
Analysis of Cash Flows
Net cash flows provided from (used for) operating, investing, and financing activities for the six months ended June 30, 2022 and 2021 are presented in the following table:
| | | | | | | | | | | | | | | | | | | | |
Net cash provided from
(used for): | Southern Company | Alabama Power | Georgia
Power | Mississippi Power | Southern Power | Southern Company Gas |
| (in millions) |
Six Months Ended June 30, 2022 | | | | | | |
| Operating activities | $ | 3,579 | | $ | 510 | | $ | 926 | | $ | 112 | | $ | 552 | | $ | 1,478 | |
| Investing activities | (3,460) | | (889) | | (1,668) | | (133) | | (73) | | (658) | |
| Financing activities | (213) | | 227 | | 939 | | (18) | | (403) | | (650) | |
| | | | | | |
Six Months Ended June 30, 2021 | | | | | | |
| Operating activities | $ | 2,904 | | $ | 584 | | $ | 1,313 | | $ | 41 | | $ | 411 | | $ | 722 | |
| Investing activities | (4,026) | | (893) | | (1,730) | | (117) | | (601) | | (668) | |
| Financing activities | 1,671 | | 506 | | 457 | | 515 | | 196 | | (25) | |
Fluctuations in cash flows from financing activities vary from year to year based on capital needs and the maturity or redemption of securities.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Southern Company
Net cash provided from operating activities increased $675 million for the six months ended June 30, 2022 as compared to the corresponding period in 2021 primarily due to the timing of vendor payments and increased natural gas cost recovery at the natural gas distribution utilities, partially offset by the timing of customer receivable collections and decreased fuel cost recovery at the traditional electric operating companies.
The net cash used for investing activities for the six months ended June 30, 2022 was primarily related to the Subsidiary Registrants' construction programs.
The net cash used for financing activities for the six months ended June 30, 2022 was primarily related to common stock dividend payments, largely offset by an increase in short-term debt and net issuances of long-term debt.
Alabama Power
Net cash provided from operating activities decreased $74 million for the six months ended June 30, 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 and customer refunds issued in 2021.
The net cash used for investing activities for the six months ended June 30, 2022 was primarily related to gross property additions.
The net cash provided from financing activities for the six months ended June 30, 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 $387 million for the six months ended June 30, 2022 as compared to the corresponding period in 2021 primarily due to decreased fuel cost recovery and the timing of customer receivable collections, partially offset by the timing of vendor payments.
The net cash used for investing activities for the six months ended June 30, 2022 was primarily related to gross property additions, including a total of approximately $500 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 six months ended June 30, 2022 was primarily related to net issuances of senior notes, capital contributions from Southern Company, and a net increase in short-term borrowings, partially offset by common stock dividend payments.
Mississippi Power
Net cash provided from operating activities increased $71 million for the six months ended June 30, 2022 as compared to the corresponding period in 2021 primarily due to the timing of vendor payments, partially offset by the timing of customer receivable collections.
The net cash used for investing activities for the six months ended June 30, 2022 was primarily related to gross property additions.
The net cash used for financing activities for the six months ended June 30, 2022 was primarily related to common stock dividend payments, partially offset by capital contributions from Southern Company and an increase in commercial paper borrowings.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Southern Power
Net cash provided from operating activities increased $141 million for the six months ended June 30, 2022 as compared to the corresponding period in 2021 primarily due to an increase in wholesale revenues driven by higher market prices of energy, the timing of vendor payments, and an increase in the utilization of tax credits in 2022, partially offset by the timing of customer receivable collections.
The net cash used for investing activities for the six months ended June 30, 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 six months ended June 30, 2022 was primarily related to the repayment of senior notes at maturity, common stock dividend payments, and net capital distributions to noncontrolling interests, partially offset by a capital contribution from Southern Company and an increase in commercial paper borrowings.
Southern Company Gas
Net cash provided from operating activities increased $756 million for the six months ended June 30, 2022 as compared to the corresponding period in 2021 primarily due to increased natural gas cost recovery and the timing of vendor payments.
The net cash used for investing activities for the six months ended June 30, 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 six months ended June 30, 2022 was primarily related to net repayments of short-term debt, common stock dividend payments, and repayment of medium-term notes, partially offset by capital contributions from Southern Company.
Significant Balance Sheet Changes
Southern Company
Significant balance sheet changes for the six months ended June 30, 2022 included:
•an increase of $1.7 billion in total property, plant, and equipment primarily related to the Subsidiary Registrants' construction programs;
•an increase of $1.1 billion in notes payable due to an increase in short-term bank debt and commercial paper borrowings;
•an increase of $0.8 billion in accumulated deferred income taxes primarily related to the utilization of ITCs in 2022 and an increase in under recovered fuel clause revenues, as discussed further below;
•an increase of $0.7 billion in total stockholders' equity primarily related to net income, partially offset by common stock dividend payments;
•an increase of $0.7 billion in accounts payable primarily related to the timing of vendor payments;
•an increase of $0.6 billion in other deferred charges and assets primarily related to an increase in under recovered fuel clause revenues at Georgia Power due to higher fuel and purchased power costs;
•an increase of $0.5 billion in regulatory assets associated with AROs primarily due to a decrease of $0.4 billion in the fair value of the investments held in Alabama Power's and Georgia Power's nuclear decommissioning trusts; and
•an increase of $0.5 billion in customer accounts receivable primarily related to the timing of collections.
See "Financing Activities" herein and Notes (B), (G), and (I) 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 six months ended June 30, 2022 included:
•an increase of $881 million in common stockholder's equity primarily due to capital contributions from Southern Company, partially offset by dividends paid to Southern Company;
•an increase of $361 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 $298 million in regulatory assets associated with AROs primarily due to a decrease of $201 million in the fair value of the investments held in Alabama Power's nuclear decommissioning trust.
See Note (I) to the Condensed Financial Statements herein for additional information.
Georgia Power
Significant balance sheet changes for the six months ended June 30, 2022 included:
•an increase of $1.1 billion in total property, plant, and equipment primarily related to the construction of generation, transmission, and distribution facilities, including $534 million for Plant Vogtle Units 3 and 4 (net of a pre-tax charge of $52 million recorded in the second quarter 2022 for estimated probable loss);
•an increase of $914 million in long-term debt (including securities due within one year) primarily due to net issuances of senior notes;
•an increase of $663 million in common stockholder's equity primarily due to net income and capital contributions from Southern Company, partially offset by dividends paid to Southern Company;
•an increase of $538 million in deferred under recovered fuel clause revenues due to higher fuel and purchased power costs;
•an increase of $400 million in notes payable due to an increase in short-term bank debt;
•an increase of $299 million in accumulated deferred income taxes primarily due to the increase in under recovered fuel clause revenues and the expected reduction in federal and state credit carryforward balances in 2022;
•an increase of $283 million in customer accounts receivable primarily due to higher customer usage and the timing of collections; and
•an increase of $252 million in regulatory assets associated with AROs primarily due to a decrease of $192 million in the fair value of the investments held in Georgia Power's nuclear decommissioning trust.
See "Financing Activities – Georgia Power" herein and Note (B) under "Georgia Power – Nuclear Construction" and Note (I) to the Condensed Financial Statements herein for additional information.
Mississippi Power
Significant balance sheet changes for the six months ended June 30, 2022 included:
•an increase of $54 million in common stockholder's equity related to net income and capital contributions from Southern Company, partially offset by dividends paid to Southern Company; and
•an increase of $52 million in customer accounts receivables primarily due to fuel under recovery.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Southern Power
Significant balance sheet changes for the six months ended June 30, 2022 included:
•a decrease of $724 million in long-term debt (including securities due within one year) primarily due to the redemption of senior notes;
•an increase of $281 million in common stockholder's equity primarily due to capital contributions from Southern Company and net income, partially offset by common stock dividend payments and distributions to noncontrolling interests; and
•an increase of $256 million in accumulated deferred income tax liabilities primarily related to the utilization of ITCs in 2022.
See "Financing Activities – Southern Power" herein and Note (G) to the Condensed Financial Statements herein for additional information.
Southern Company Gas
Significant balance sheet changes for the six months ended June 30, 2022 included:
•a decrease of $693 million in notes payable due to repayments of short-term debt and commercial paper borrowings;
•an increase of $544 million in common stockholder's equity related to net income and capital contributions from Southern Company, partially offset by dividends paid to Southern Company;
•an increase of $440 million in total property, plant, and equipment primarily related to the construction of transportation and distribution assets and additional infrastructure investment; and
•a decrease of $230 million in other regulatory assets, deferred primarily due to a $192 million reduction in natural gas cost under recovery.
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 six months of 2022:
| | | | | | | | | | | | | | | | | | |
| | | | Maturities and Redemptions |
| Company | Senior Note Issuances | | | | | Senior
Notes | | Other Long-Term Debt(*) |
| (in millions) |
| | | | | | | | |
| Alabama Power | $ | 700 | | | | | | $ | 550 | | | $ | — | |
| Georgia Power | 1,500 | | | | | | 400 | | | 171 | |
| | | | | | | | |
| Southern Power | — | | | | | | 677 | | | — | |
| Southern Company Gas | — | | | | | | — | | | 46 | |
| Other | — | | | | | | — | | | 7 | |
| | | | | | | | |
| Southern Company | $ | 2,200 | | | | | | $ | 1,627 | | | $ | 224 | |
(*)Includes reductions in finance lease obligations resulting from cash payments under finance leases and, for Georgia Power, principal amortization payments totaling $45 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.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
In addition to any financings that may be necessary to meet capital requirements and contractual obligations, the Registrants plan to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.
Southern Company
During the first half of 2022, Southern Company issued approximately 3.1 million shares of common stock primarily through employee equity compensation plans and received proceeds of approximately $61 million.
In March 2022, Southern Company entered into a $400 million short-term floating rate bank loan bearing interest based on term SOFR.
In May 2022, Southern Company borrowed $100 million pursuant to a short-term uncommitted bank credit arrangement bearing interest at a rate agreed upon by Southern Company and the bank from time to time and payable on demand, following specified notice by the bank.
See Note (F) to the Condensed Financial Statements herein under "Equity Units" for information regarding Southern Company's May 2022 remarketing of its Series 2019A and Series 2019B Remarketable Junior Subordinated Notes. Southern Company did not receive any proceeds from the remarketing.
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.
In June 2022, Alabama Power redeemed the following series of preferred stock: 4.20% Preferred Stock, Par Value $100 Per Share, 4.60% Preferred Stock, Par Value $100 Per Share, 4.92% Preferred Stock, Par Value $100 Per Share, 4.52% Preferred Stock, Par Value $100 Per Share, 4.64% Preferred Stock, Par Value $100 Per Share, and 4.72% Preferred Stock, Par Value $100 Per Share. The redemption price per share for each series of preferred stock equaled the redemption price per share provided in Note 8 to the financial statements under "Outstanding Classes of Capital Stock – Alabama Power" in Item 8 of the Form 10-K, plus accrued and unpaid dividends to the redemption date.
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, which it repaid in May 2022.
In each of March and April 2022, Georgia Power entered into a $200 million short-term floating rate bank loan bearing interest based on term SOFR.
In May 2022, Georgia Power issued $700 million aggregate principal amount of Series 2022A 4.70% Senior Notes due May 15, 2032 and $800 million aggregate principal amount of Series 2022B 5.125% Senior Notes due May 15, 2052. An amount equal to the net proceeds of the Series 2022B Senior Notes will be allocated to finance or refinance, in whole or in part, one or more renewable energy projects and/or expenditures and programs related to enabling opportunities for diverse and small businesses/suppliers.
In May 2022, Georgia Power repaid its $125 million long-term bank loan that was scheduled to mature in June 2022.
Subsequent to June 30, 2022, Georgia Power repaid at maturity $53 million aggregate principal amount of Development Authority of Floyd County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Hammond Project), First Series 2010.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (Continued)
Mississippi Power
In June 2022, Mississippi Power repaid $20 million, which was borrowed in March 2022 under its $125 million revolving credit arrangement.
Southern Power
In June 2022, Southern Power repaid at maturity €600 million (approximately $677 million) aggregate principal amount of Series 2016A 1.00% Senior Notes.
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 also 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.
During the second quarter 2022, Atlanta Gas Light repaid at maturity $46 million aggregate principal amount of medium-term notes with a weighted average interest rate of 8.63%.
Credit Rating Risk
At June 30, 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.
The maximum potential collateral requirements under these contracts at June 30, 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 | $ | 33 | | $ | 1 | | $ | — | | $ | — | | $ | 32 | | $ | — | |
| At BBB- and/or Baa3 | 414 | | 2 | | 61 | | 1 | | 353 | | — | |
| At BB+ and/or Ba1 or below | 1,948 | | 416 | | 917 | | 316 | | 1,215 | | 7 | |
(*)Southern Power has PPAs that could require collateral, but not accelerated payment, in the event of a downgrade of Southern Power's credit. The PPAs require credit assurances without stating a specific credit rating. The amount of collateral required would depend upon actual losses resulting from a credit downgrade. Southern Power had $106 million of cash collateral posted related to PPA requirements at June 30, 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 six months ended June 30, 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 Company's, Alabama Power's, Georgia Power's, Mississippi Power's, Southern Power's, or Southern Company Gas' internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended) during the second quarter 2022 that have materially affected or are reasonably likely to materially affect Southern Company's, Alabama Power's, Georgia Power's, Mississippi Power's, Southern Power's, or Southern Company Gas' internal control over financial reporting.
