Xcel Energy Inc. — Q2 2023 Form 10-Q
Business context and period. Xcel Energy is a regulated electric and natural gas utility holding company. This unaudited filing covers the three and six months ended June 30, 2023; interim results are seasonal and are not necessarily indicative of full-year performance. Unless noted, amounts are in millions of dollars.
Financial results and position
| Metric | Q2 2023 | Q2 2022 | Six months 2023 | Six months 2022 |
|---|---|---|---|---|
| Operating revenue | $3,022 | $3,424 | $7,102 | $7,175 |
| Operating income | $418 | $469 | $991 | $979 |
| Net income | $288 | $328 | $706 | $708 |
| Diluted EPS | $0.52 | $0.60 | $1.28 | $1.30 |
| Operating cash flow | Not separately provided for quarter | $2,455 | $1,988 | |
| Capital/construction expenditures | Not separately provided for quarter | $2,599 | $2,040 |
- Q2 revenue fell about 12% year over year, while six-month revenue declined about 1%. Lower electric revenue was partly offset by higher six-month natural gas revenue.
- Q2 operating income declined about 11% and net income about 12%; first-half net income was nearly flat. Approximate operating margin was 13.8% in Q2 2023 versus 13.7% a year earlier, and 14.0% for the first half versus 13.6%.
- Electric margin was $1,571 in Q2, down from $1,742; six-month electric margin was $3,217 versus $3,281. Natural gas margin was $223 in Q2 versus $225, and $667 for the first half versus $605.
- Operating cash flow rose $467 year over year, attributed primarily to lower natural gas prices affecting receivables and payables and continued collection of deferred fuel and energy costs. Investing cash use increased to $2,639, largely reflecting higher capital expenditures. Financing cash provided was $348.
- At June 30, cash was $275. Long-term debt was $24,015, with $1,051 current portion and $544 short-term debt. Committed revolving facilities totaled $3,550, of which $2,960 was available at June 30. Total assets were $61,658 and stockholders’ equity was $16,914.
- Six-month dividends paid were $536; dividends declared were $1.04 per share. Weighted average diluted shares were 552 million for Q2 and 551 million for the first half.
Changes, outlook and management commentary
- Management attributed lower Q2 EPS primarily to unfavorable weather in Colorado and SPS territories, higher O&M and interest costs, and regulatory outcomes that did not fully offset those pressures. Higher interest expense reflected rising rates and increased debt.
- 2023 GAAP and ongoing EPS guidance is $3.30–$3.40. Assumptions include normal weather for the rest of the year, approximately 1% growth in weather-normalized retail electric sales, relatively flat firm natural gas sales, O&M expense down about 3%, and interest expense up $80–$90. The filing says ongoing and GAAP earnings were equal in the periods reported; future unplanned adjustments could differ.
- Long-term objectives are annual EPS growth of 5%–7% from a 2022 base of $3.15, annual dividend growth of 5%–7%, a 60%–70% payout ratio, and senior secured debt ratings in the A range.
- After quarter-end, the Minnesota regulator approved a three-year electric rate increase of approximately $311, based on a 9.25% ROE; Xcel planned to seek reconsideration. Other rate cases and regulatory decisions remain pending, making recovery assumptions important to guidance.
- Capital needs remain substantial: first-half capital/construction expenditures were $2,599. The company issued $1,775 of long-term bonds in the first half and planned additional debt issuance in the third quarter, alongside equity funding.
Risks, contingencies and unusual items
- Marshall Fire: The sheriff’s report identified the most probable cause of the second ignition as hot particles from PSCo power lines, while also stating an underground coal fire could not be ruled out. PSCo disputes that its lines caused the ignition. The company reported approximately 586 plaintiffs and could not estimate possible losses; damages could exceed approximately $500 of insurance coverage and materially affect results or cash flows.
- Comanche Unit 3 litigation: CORE’s expert estimated damages of $270; PSCo disputes the claims. Trial was scheduled for October 2023.
- Regulatory and environmental exposure: Potential costs include coal ash corrective actions, Clean Water Act cooling-water requirements, and proposed emissions and PFAS rules. The company generally expects recovery through rates, but timing, final requirements and recoverability remain uncertain. Proposed NOx rule costs could be significant.
- Operations and funding: Supply constraints for transformers, meters and solar panels may delay projects and customer connections and raise costs. Commodity, interest-rate, counterparty, weather, cyber, workforce and regulatory risks also remain. Management reported no material change in previously disclosed risk factors.
- The Monticello tritium release was repaired and is being monitored and mitigated; the filing states it does not present a risk to human health or the environment. No material impact from adopted or issued accounting pronouncements was reported.
Most important facts for investors to verify
- Whether the $3.30–$3.40 EPS outlook remains achievable under actual weather, sales, cost and regulatory outcomes.
- Final outcomes and timing of key rate proceedings, especially Minnesota, Colorado, Texas and New Mexico, and the resulting recovery of investment and operating costs.
- Marshall Fire investigation and litigation developments, including potential liability relative to insurance coverage; also monitor the Comanche Unit 3 case.
- Capital spending, debt issuance, interest costs, available liquidity and credit ratings as the investment program proceeds.
- Whether supply-chain and environmental-rule costs affect project schedules, customer service, cash flow or rate recovery.