NRG Energy, Inc. — Q1 2012 Form 10-Q
Reporting period: Three months ended March 31, 2012; comparisons are with Q1 2011 unless otherwise noted. NRG operates wholesale power generation, retail electricity businesses and alternative-energy projects, including solar and wind. Figures below are in millions of dollars unless stated otherwise.
Financial performance and position
- Revenue and operating results: Operating revenue was $1,862, down 7% from $1,995. Operating costs and expenses rose 21% to $2,032, producing an operating loss of $170 versus operating income of $314.
- Profit and per-share results: Net loss attributable to NRG was $207, compared with $260; loss available to common stockholders was $209, or $0.92 per diluted share, versus $262, or $1.06 per share. The smaller net loss chiefly reflects the absence of the prior-year $481 NINA investment impairment and $28 debt-extinguishment loss, despite weaker operating results. The 2012 income tax benefit was $120.
- Key operating drivers: Net mark-to-market results for economic hedges fell by $298 year over year, from a $133 gain to a $165 loss. Conventional generation gross margin declined $72, reflecting outages, lower realized prices and coal-to-gas switching. Retail gross margin was $280 versus $285; alternative-energy gross margin increased to $20 from $9.
- Cash flow: Operating cash flow was negative $76, down from positive $216. Investing used $543, including $639 of cash capital expenditures; financing provided $527. Cash and cash equivalents declined $91 to $1,014.
- Debt and equity: Long-term debt and capital leases totaled $10,221, including $71 current, compared with $9,832 at year-end 2011. Total liabilities were $20,648 and stockholders’ equity was $7,633. The company had $6.1 billion of unsecured senior notes outstanding.
- Liquidity: Reported liquidity excluding collateral received was $2,372 at March 31, including $1,014 cash, $217 restricted cash and $1,141 available on the revolving credit facility. Some restricted cash supports project equity obligations and is not freely available. Total commercial cash collateral posted was $495, with $707 of letters of credit outstanding.
- Capital and market-risk measures: The company accrued but had not paid $327 of capital expenditures, primarily for solar construction. Commodity portfolio VaR was $51 at quarter-end. Management estimated a $1/MMBtu natural-gas price movement could change derivative value by about $245 and margin collateral by about $262.
Changes versus the prior comparable period
- Revenue decreased $133, while operating expenses increased $351; the shift from operating income to operating loss was primarily driven by hedge mark-to-market results and lower conventional-generation margin.
- Texas generation gross margin fell $73, with higher planned and unplanned outages, an unplanned STP nuclear outage, lower realized prices and reduced coal generation among the cited drivers. Northeast margin declined $11, while South Central margin was nearly flat.
- Retail revenue increased modestly, with customer growth and Energy Plus acquisition contributions offset by mild winter weather, lower C&I pricing and increased risk-management costs. Average mass customer locations increased to 2.077 million from 1.812 million.
- Capital spending accelerated substantially, particularly for solar projects. Debt and project financing increased, while cash fell; revolving-facility availability improved mainly after the Agua Caliente interest sale reduced letter-of-credit requirements.
Outlook, management commentary and material risks
- Capital plans: NRG expected approximately $3,246 of capital expenditures for the remainder of 2012, with $2,315 identified as funded by debt financing and $205 by third-party equity partners; its estimated net requirement was $595. For 2012, the company planned about $271 of maintenance and environmental spending and $425 for solar and other projects under development.
- Shareholder returns and debt: The company announced an intended annual common dividend of $0.36 per share, with the first quarterly payment expected in Q3 2012. It also intended to refinance the remaining $1.1 billion of 2017 notes, subject to market conditions. Management said liquidity and operating cash flows should be adequate for operating needs, maintenance capital expenditures and preferred dividends.
- Development outlook: Agua Caliente’s schedule was accelerated after quarter-end; NRG expected 245 MW online during 2012 and the full project by March 2014. CVSR operations were expected to begin in phases in Q3 2012; Alpine was expected to reach commercial operation in late Q3 2012. These schedules and financing needs depend on project execution and approvals.
- Environmental exposure: Estimated environmental capital expenditures for 2012–2016 were approximately $553, primarily for air-pollution controls and cooling-water intake modifications. Final regulatory requirements and legal challenges could change scope, timing and cost.
- Legal and regulatory matters: NRG reached a CDWR settlement agreement in principle in March; the executed agreement was submitted to FERC on April 27, after quarter-end. It includes a $20 cash payment, accrued in Q1, plus an expected approximately $100 of spending over four to six years for EV charging infrastructure and parking-space wiring. FERC approval was expected in Q2 or Q3 2012. A Clean Air Act case concerning Big Cajun II remained unresolved, with a liability-phase trial scheduled for October 2012 if the case proceeded; NRG could not predict the impact.
- Other key risks: Power and fuel price volatility, generation outages, weather, collateral demands, counterparty performance, substantial indebtedness, regulatory and environmental changes, and the ability to finance and complete development projects could affect earnings and liquidity. ERCOT proposed higher system-wide offer caps, which NRG said could materially affect its retail and wholesale operations.
Important facts for investors to verify
- Whether operating performance and hedge mark-to-market results recover, and how much of Q1’s loss reflects non-cash or unsettled valuation changes.
- Available unrestricted liquidity after project collateral, letters of credit and energy-market margin needs, including exposure to commodity-price changes.
- Actual project spending, financing drawdowns, partner contributions and commercial-operation timing for Agua Caliente, CVSR, Alpine and other solar developments.
- FERC action on the CDWR settlement, the settlement’s ultimate cost and schedule, and developments in the Big Cajun II litigation.
- Whether the planned common dividend and refinancing proceed, and their effects on leverage, liquidity and covenant flexibility.
- Final environmental and ERCOT market rules, and resulting compliance costs, operating impacts and capital requirements.