Southern Company Q1 2024 Form 10-Q Summary
Business context and reporting period
Quarter ended March 31, 2024; filed May 1, 2024. This combined, unaudited filing covers Southern Company and five subsidiaries. Southern Company’s principal businesses are regulated electric utilities, wholesale power generation, and natural gas distribution and related services. Management cautions that seasonal quarterly results are not necessarily indicative of full-year results.
Key financial metrics
| Southern Company consolidated | Q1 2024 | Q1 2023 | Change |
|---|---|---|---|
| Operating revenues | $6.646 billion | $6.480 billion | +2.6% |
| Operating income | $1.703 billion | $1.218 billion | +39.8% |
| Net income attributable to Southern Company | $1.129 billion | $862 million | +31.0% |
| Diluted earnings per share | $1.03 | $0.79 | +$0.24 |
| Operating margin | 25.6% | 18.8% | +6.8 percentage points |
| Operating cash flow | $1.311 billion | $844 million | +$467 million |
Cash flow from operations exceeded property additions of $1.770 billion by $459 million; total investing cash outflow was $2.385 billion. Cash, cash equivalents, and restricted cash ended the quarter at $832 million, versus $921 million at year-end 2023. The company paid $733 million of common-stock dividends in the cash-flow statement.
At March 31, total assets were $140.120 billion, long-term debt was $59.361 billion, securities due within one year were $1.964 billion, and notes payable were $2.445 billion. These three debt categories totaled $63.770 billion, compared with $62.000 billion at December 31, 2023. Current liabilities exceeded current assets by $915 million. Unused committed bank credit was $7.577 billion; management said the registrants were in compliance with applicable debt covenants.
Material changes and operating drivers
- Electric retail revenues rose $342 million, primarily from rates and pricing, sales growth, and colder weather. Management cited Vogtle Unit 3 entering Georgia Power’s rate base, Georgia rate increases, and Alabama Power rate changes as contributors.
- Natural gas revenues declined $168 million, largely because lower gas prices reduced cost-recovery revenues; Southern Company Gas also reported warmer weather and lower gas-cost recovery versus the prior-year quarter. These cost-recovery movements generally offset related fuel costs and do not, by themselves, materially drive utility earnings.
- Net income increased despite higher interest expense, depreciation and amortization, operations and maintenance costs, and income taxes. Interest expense, net of capitalized amounts, rose $83 million to $665 million, primarily due to higher rates and average borrowings.
- By subsidiary, Georgia Power net income rose to $437 million from $296 million; Alabama Power rose to $333 million from $255 million; Southern Company Gas rose to $409 million from $309 million. Mississippi Power fell to $50 million from $58 million, and Southern Power income attributable to it declined to $96 million from $102 million.
Outlook, commentary, risks, and unusual items
- Vogtle Unit 4: It reached initial criticality on February 14 and first generated electricity on March 1; it entered service on April 29, after quarter-end. Georgia Power’s forecast project capital cost was $10.753 billion, with an estimated $145 million remaining at March 31. Its estimated construction financing costs were approximately $3.53 billion. Georgia Power added $5.462 billion of construction and capital costs and $647 million of related rate-base items to retail rate base effective April 29. Annual retail base revenues increased approximately $730 million, with average base rates adjusted approximately 5% effective May 1; the NCCR tariff was eliminated at that time. Cost recovery, project estimates, and the rate impacts remain important items to monitor.
- Other post-quarter developments: Georgia Power’s updated resource plan was approved April 16, including authority for up to 1,400 MW of Plant Yates combustion turbines and battery-storage plans. Mississippi Power’s April 26 resource-plan filing proposed retiring specified generating units by the end of 2028, subject to regulatory review. A Georgia Power transmission-asset sale closed after quarter-end for $341 million and is expected to produce an approximately $110 million pretax gain in Q2.
- Investment and funding: Southern Power continued solar construction; remaining aggregate construction costs for the Millers Branch and South Cheyenne projects were estimated at $500 million to $620 million. Management said Southern Power’s generating assets were 97% under contract through 2028 and 89% through 2033, with approximately 12 years’ average remaining contract duration.
- Environmental and legal exposure: New EPA rules released April 25 concerning wastewater, coal-ash units, and greenhouse-gas emissions may result in significant compliance costs; the ultimate impact was not determinable. A False Claims Act lawsuit alleging improper DOE grant procurement relating to the abandoned Kemper project could materially affect Southern Company and Mississippi Power. Alabama Power’s Plant Barry coal-ash matter and Georgia Power’s Plant Scherer groundwater and air claims also remain relevant; potential loss for the Scherer matters could not be estimated. Mississippi Power reported a separate customer refund litigation matter as concluded.
- Other risks and outlook: Management highlighted regulatory cost recovery, construction cost and schedule risk, interest rates and access to capital, demand and weather variability, fuel prices, environmental requirements, and reliability and operational risks. The filing text does not provide a clear numerical full-year earnings or EPS guidance. Management described financial condition as stable and said it would continue monitoring capital-market access and liquidity.
Most important facts for investors to verify
- Vogtle Unit 4’s operating performance, final project costs, remaining expenditures, and realized rate recovery following its April 29 in-service date.
- Whether Georgia Power’s approximately $730 million annual base-revenue increase and the related rate changes are implemented and sustained as described.
- Actual Q2 recognition of the approximately $110 million pretax gain from the transmission-asset sale.
- EPA rule implementation, utility-specific compliance spending, and developments in the Kemper, Plant Barry, and Plant Scherer matters.
- Debt issuance, interest expense, capital spending, and liquidity needs as the company funds construction and other system investments.