Quanta Services, Inc. — Q1 2017 Form 10-Q
Business context and period: Quanta provides specialty infrastructure contracting services in electric power, oil and gas, and communications markets. This unaudited filing covers the three months ended March 31, 2017, compared with Q1 2016. Results are seasonal; management says first-quarter activity is typically lower, and interim results are not necessarily indicative of the full year.
Key financial metrics
| Metric | Q1 2017 | Q1 2016 / comparison |
|---|---|---|
| Revenue | $2,178.2 million | $1,713.7 million; up 27.1% |
| Gross profit / margin | $266.2 million / 12.2% | $203.3 million / 11.9% |
| Operating income / margin | $75.1 million / 3.4% | $37.3 million / 2.2% |
| Net income attributable to common stock | $48.3 million; $0.31 per share | $20.5 million; $0.13 per share |
| Operating cash flow | $(3.8) million | $205.8 million |
| Cash and cash equivalents | $106.5 million at March 31 | $112.2 million at December 31, 2016 |
| Total debt | $423.3 million | $358.4 million at December 31, 2016 |
| Working capital | $1.21 billion | — |
Operating cash flow deteriorated mainly because of working-capital investment as larger pipeline projects entered full construction, late-quarter revenue timing, and billing delays on two Canadian transmission projects. Net credit-facility borrowings were $65.8 million. Quanta reported $1.07 billion of remaining availability under its $1.81 billion revolving facility and compliance with its debt covenants. The reported credit-facility weighted-average interest rate was 2.61%.
Material changes versus Q1 2016
- Oil and gas revenue rose 82.0% to $958.7 million, as large pipeline projects moved into full construction. Segment operating income increased to $38.8 million from $5.8 million; margin rose to 4.0% from 1.1%.
- Electric power revenue increased 2.7% to $1.22 billion; segment operating income rose 14.1% to $99.7 million, with margin improving to 8.2% from 7.4%.
- Consolidated profitability benefited from stronger pipeline and emergency restoration contributions and the absence of the prior-year $21.3 million Alaska power-plant project loss. Q1 2017 SG&A included higher compensation and litigation costs and a $1.9 million loss on a planned barge sale.
- The effective tax rate fell to 31.8% from 39.2%, including a $4.9 million tax benefit related to the adopted share-based-payment accounting standard.
- Total backlog declined to $9.24 billion from $9.75 billion at year-end. Electric power backlog increased to $6.76 billion; oil and gas backlog decreased to $2.48 billion. Management attributed about $100 million of the oil and gas 12-month backlog reduction to cancellation of a pipeline project; Quanta received a termination fee.
Outlook, risks and unusual items
- Outlook: Management described a positive long-term outlook and expected a renewed multiyear up-cycle across both segments. It said electric power backlog should remain strong through 2017 and expected significant larger pipeline project execution in 2017, potentially concentrated in the first half. These are forward-looking expectations, not quantitative revenue or earnings guidance.
- Capital spending: 2017 capital expenditures were expected to total $210–$225 million; $47.0 million was spent in Q1.
- Project execution: Weather delays on a natural-gas transmission project led to $16.5 million of recognized losses in Q1. The project was approximately 85% complete. Potential claims are being developed, but no recovery was included in the loss estimate; additional losses are possible and not currently estimable.
- Receivables and concentration: One electric-power customer represented approximately 16% of net receivables, or $300.4 million, including $191.1 million of costs and estimated earnings in excess of billings. The balance relates to two remote northeastern Canadian projects with invoicing and documentation delays and includes negotiated change orders and claims. DSO increased to 78 days from 76 days a year earlier.
- Claims and contingencies: Quanta had recognized $147.1 million of revenue for change orders and claims under negotiation; ultimate collection may differ. A California wage-and-hour case carries a reasonably possible loss of up to approximately $23 million, though management did not believe a material loss was probable. The Central States multiemployer pension withdrawal matter had a stated reasonably possible loss range of $40.1–$55.4 million; $19.1 million had been paid toward an assessment, and final liability remains uncertain.
- Other exposures: Outstanding performance bonds were approximately $3.4 billion, with estimated costs to complete of $910 million. Maximum guaranteed residual values on certain equipment leases were $573.3 million. These are contingent exposures, not amounts reported as current debt.
- Market and operating risks: Management cited commodity-price sensitivity, regulatory and permitting delays, project cancellation or slippage, adverse weather, competitive pricing, skilled-labor availability, fixed-price project execution, customer collection risk, foreign-exchange movements, and potential multiemployer pension and self-insurance liabilities. It reported no interim goodwill impairment charge, but noted oil-and-gas units exposed to weak markets and customer spending constraints.
Investor verification priorities
- Track operating cash conversion, receivables, unbilled project balances, DSO, and progress resolving the Canadian project billing delays.
- Verify whether the $16.5 million pipeline-project loss is final or whether further cost overruns or claim recoveries arise.
- Monitor backlog conversion and cancellations, especially the oil-and-gas decline and the expected timing and margins of large projects.
- Review the Central States pension matter, Benton litigation, and the collectability of negotiated change orders and claims.
- Reconcile capital spending and working-capital needs with available facility capacity, debt growth, and the company’s expected operating cash flows.