NRG Energy, Inc. — Q1 2013 Form 10-Q
Business context and reporting period
Quarter ended March 31, 2013. NRG operates wholesale power generation, retail energy businesses and alternative-energy projects. Results include GenOn from its December 14, 2012 acquisition; therefore, year-over-year comparisons are not fully comparable, particularly in generation and operating costs.
Financial and operating performance
| Metric | Q1 2013 | Q1 2012 |
|---|---|---|
| Operating revenue | $2.081 billion | $1.862 billion |
| Operating loss | $259 million | $170 million |
| Net loss attributable to NRG | $328 million | $207 million |
| Loss per diluted share | $1.02 | $0.92 |
| Cash from operating activities | $(124) million | $(76) million |
| Cash used in investing activities | $(836) million | $(543) million |
| Cash from financing activities | $580 million | $527 million |
- Revenue rose 12%, but total operating costs increased 15% to $2.340 billion. Higher GenOn-related operating and maintenance costs, depreciation, corporate expenses and $32 million in acquisition and integration costs contributed to the larger operating loss.
- Pre-tax loss widened to $476 million from $326 million. NRG recorded $28 million of debt-extinguishment loss and $196 million of interest expense. Net mark-to-market results from economic hedging activities declined by $98 million year over year; the filing reports $306 million of total unrealized losses in these activities.
- Retail gross margin was $276 million, down $4 million. Conventional generation gross margin increased $304 million, substantially reflecting GenOn, while alternative-energy gross margin rose to $51 million from $20 million, supported by additional solar generation.
- Cash and cash equivalents were $1.707 billion at quarter-end, down from $2.087 billion at December 31, 2012. Total liquidity excluding collateral received was $3.085 billion, including $1.157 billion of revolving-credit availability. Management said liquidity and operating cash flows should be adequate for operating needs, capital spending and dividends.
- Long-term debt and capital leases totaled $16.470 billion, including $556 million of current maturities; long-term debt fair value was $17.133 billion. Debt repurchases generated a $28 million extinguishment loss. Stockholders’ equity was $10.196 billion.
- Capital expenditures were $813 million in cash for the quarter. NRG estimated $1.609 billion of capital expenditures for the remainder of 2013, or $786 million net of expected financing and partner/grant funding.
Changes, outlook and risks
- GenOn’s acquisition added significant generation assets and operating costs to the comparison. Management attributed the $304 million increase in conventional-generation gross margin principally to GenOn’s contribution in the East region.
- NRG planned to increase its annual common dividend by 33% to $0.48 per share; a $0.12 quarterly dividend was declared for payment in May. The company was authorized to repurchase $200 million of shares and intended to complete the remaining approximately $175 million by year-end, subject to capital availability, market conditions and legal requirements.
- Management estimated environmental capital expenditures of approximately $528 million for 2013–2017. A consent decree for Big Cajun II requires emissions controls, conversion of one coal unit to natural gas, a $3.5 million penalty and $10.5 million of mitigation projects.
- Project developments included delays at the Ivanpah solar project: the first unit was expected by the end of September 2013 and the remaining units in Q4 2013. The filing also described expected commercial-operation dates for other projects, including El Segundo in August 2013. Such schedules and project financing remain subject to execution and other risks.
- Key risks include volatile power, fuel and emissions prices; weather, outages and transmission constraints; collateral and counterparty demands; substantial indebtedness; regulatory and environmental requirements; and integration of GenOn. NRG disclosed a commodity portfolio VaR of $89 million at March 31, 2013 and sensitivity of derivative value to natural-gas prices.
- Material matters included environmental proceedings and remediation obligations, pending or proposed legal settlements, and uncertainty over regulatory rules and market capacity prices. The Maryland fly-ash matters were resolved by a court-approved consent decree on April 30, 2013; certain other settlements remained subject to court or regulatory approval.
Important facts for investors to verify
- How much of the year-over-year earnings change reflects GenOn consolidation versus underlying performance, and the expected timing and costs of merger integration.
- Drivers of recurring operating cash flow and collateral needs, given negative Q1 operating cash flow and substantial cash use for capital spending.
- Debt maturities, interest costs and available borrowing capacity, including the distinction between recourse and non-recourse project debt.
- Progress, financing, costs and commercial-operation schedules for solar, generation and carbon-capture projects, especially Ivanpah.
- Final costs and compliance obligations from environmental matters, including the Maryland ash-site settlement and Big Cajun II decree.
- Whether planned dividends and share repurchases remain supportable alongside capital commitments and balance-sheet priorities.