NRG Energy, Inc. — FY2012 Form 10-K
Reporting period: Fiscal year ended December 31, 2012. This is an annual report, not a standalone fourth-quarter filing. Financial amounts are in U.S. dollars; unless noted, amounts are in millions.
Business context
NRG operates wholesale power generation, competitive retail energy, and alternative-energy businesses. At year-end it reported 46,545 MW of global generation capacity, including 45,940 MW domestic, and served approximately 2.2 million retail customers. The December 14, 2012 acquisition of GenOn added approximately 21,440 MW of generation capacity; NRG issued 93.9 million shares. GenOn results are consolidated only from December 15, so reported 2012 comparisons are not on a full-year combined-company basis.
Financial performance and liquidity
| Metric | FY2012 | FY2011 |
|---|---|---|
| Operating revenue | $8,422 | $9,079 |
| Operating income | $350 | $635 |
| Net income attributable to NRG | $559 | $197 |
| Diluted EPS | $2.35 | $0.78 |
| Cash from operations | $1,149 | $1,166 |
| Capital expenditures, cash basis | $3,396 | $2,310 |
| Long-term debt and capital leases | $15,880 | $9,832 |
| Liquidity, excluding collateral received | $3,362 | $2,070 |
Revenue declined about 7%, while operating income fell about 45%. Retail gross margin increased to $1,378 from $1,254; conventional generation gross margin was $2,567 versus $2,337; and alternative-energy gross margin rose to $153 from $44. These segment gross-margin measures are not consolidated operating margins.
Reported earnings benefited materially from a $560 GenOn bargain-purchase gain and a $327 income-tax benefit. The tax benefit included $196 related to the acquisition and $158 of investment tax credits from Agua Caliente. Without those items, headline net income is not a straightforward measure of recurring earnings. FY2012 operating costs included $107 of acquisition and integration costs; NRG also recorded a $51 loss on debt extinguishment.
Year-end cash and cash equivalents were $2,087; total assets were $35,128 and stockholders’ equity was $10,533. Debt to total capitalization was 56.13%, compared with 52.43% in 2011. Liquidity included $1,058 of revolving-credit availability; $271 of counterparty cash collateral is excluded from the stated $3,362 liquidity figure. Operating cash flow was slightly lower despite higher reported net income, while investing cash outflow was $2,262 and financing cash inflow was $2,099.
Material changes versus the prior year
- GenOn expanded NRG’s scale and geographic footprint, but also increased debt, operating complexity, and integration requirements. The acquisition added $4,203 of long-term debt and capital leases at acquisition-date fair value.
- Year-end debt and capital leases increased by approximately $6.0 billion from 2011. The debt-to-capitalization ratio rose, although total liquidity also increased.
- Henry Hub natural-gas prices averaged $2.79/MMBtu, down 31% from 2011. Management cited lower gas and power prices, mild weather, and limited demand growth as pressure on wholesale prices.
- Net mark-to-market results for economic hedging activities deteriorated by $424 year over year. This accounting volatility does not necessarily equal realized cash performance.
- Retail customer counts rose by approximately 142,000; retail gross margin increased $124, partly reflecting a full year of Energy Plus ownership.
- Cash capital expenditures increased to $3,396, primarily reflecting solar and other development spending. NRG reported $3,152 of alternative-energy growth investment capital expenditures for the year.
Outlook, commentary, risks and unusual items
- Outlook and capital allocation: The filing does not provide a conventional earnings or revenue forecast. NRG estimated 2013 capital expenditures of $2,516 gross and $843 net of expected project financing and partner funding. It estimated $630 of environmental capital expenditures for 2013–2017. In February 2013, NRG announced a planned 33% increase in its annual common dividend to $0.48 per share and authorization to repurchase up to $200 of common stock, subject to capital availability and other constraints.
- Market exposure: Merchant generation results depend on volatile power, fuel, and capacity prices; lower gas prices can depress power prices and coal margins. Weather, outages, fuel transportation, hedging outcomes, collateral needs, and retail customer demand can also affect results and liquidity. Management reported portfolio VaR of $92 at year-end; a $0.50/MMBtu gas-price increase was estimated to reduce the net value of derivatives by about $434.
- Merger execution: Expected GenOn cost and operating synergies, interest savings, and reduced collateral needs are not assured. Pro forma results assuming the companies combined from January 1, 2012 showed $10,986 revenue and $48 net income attributable to NRG, excluding the reported bargain-purchase gain and certain transaction effects.
- Environmental and legal exposures: Potentially significant requirements include air-emission controls, water rules, coal-ash remediation, and greenhouse-gas regulation. Maryland fly-ash matters included a $47 reserve for caps, but the company could not estimate the upper range of remediation obligations. The Big Cajun II settlement contemplated a $3.5 penalty, $10.5 of mitigation projects, and emissions-control requirements. NRG also expected approximately $100 of spending over four to six years under its California settlement, in addition to a $20 cash payment made in January 2013.
- Other unusual items: The $560 acquisition gain and significant tax credits materially affected earnings. Goodwill was $1,956; management said Texas reporting-unit fair value exceeded carrying value by 16%, but only 3% under a sensitivity scenario with lower gas prices. A sustained reduction in long-term prices could lead to impairment.
Important facts for investors to verify
- How much of FY2012 earnings is repeatable after excluding the GenOn bargain-purchase gain, acquisition-related tax benefits, and other unusual items?
- What are the combined company’s ongoing debt-service needs, covenant headroom, and ability to refinance the $575 GenOn notes due in 2014?
- Are GenOn integration savings achievable, and how do full-year combined operating results compare with reported FY2012 results?
- Will the planned 2013 capital program, environmental spending, and announced dividend increase be funded without weakening liquidity or delaying projects?
- What is the ultimate cost and timing of coal-ash remediation and other environmental or legal matters, particularly the Maryland sites and Big Cajun II?
- How sensitive are generation margins, derivative values, collateral requirements, and Texas goodwill to changes in gas and power prices?