NRG ENERGY, INC. quarterly report, Q3 FY2014

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NRG Energy, Inc. — Q3 2014 Form 10-Q

Business context and reporting period

Quarter ended September 30, 2014. NRG is a U.S. competitive power company with generation, wholesale energy trading, retail supply, renewable energy and contracted infrastructure businesses. It reported approximately 52,410 MW of net global generation capacity. Major 2014 additions included EME, acquired in April, and Alta Wind, acquired in August; the company also acquired Dominion’s competitive retail electricity business.

Financial performance and position

  • Q3 revenue: $4.569 billion, up 31% from $3.490 billion. Operating income was $549 million versus $527 million; operating margin was approximately 12.0%, compared with 15.1%.
  • Q3 earnings: Net income attributable to NRG was $168 million, or $0.49 per basic share, versus $119 million, or $0.36, a year earlier. Pretax income declined to $271 million from $298 million, while income tax expense fell to $89 million from $160 million.
  • Nine-month results: Revenue was $11.676 billion, up 37%; operating income was $818 million versus $548 million. NRG reported $15 million attributable net income, versus an $89 million loss, and $0.02 per share versus a $0.30 loss per share.
  • Cash flow: Nine-month operating cash flow was $1.114 billion, up from $823 million. Investing used $2.958 billion, including $2.832 billion for acquisitions; financing provided $1.541 billion. Cash declined $301 million to $1.953 billion.
  • Liquidity: Management reported $3.594 billion of liquidity excluding collateral received, comprising $1.953 billion cash, $339 million restricted cash and $1.302 billion of available credit facilities, down from $3.695 billion at year-end 2013.
  • Debt: Debt and capital leases totaled $20.773 billion, including $854 million current, versus $16.817 billion at December 31, 2013. Interest expense for nine months rose to $809 million from $630 million.
  • Other metrics: Total assets were $40.069 billion and stockholders’ equity $11.690 billion. Common dividends were $0.14 per share for Q3; an October declaration maintained the quarterly rate, equivalent to $0.56 annualized.

Material changes versus prior period

  • Q3 revenue growth reflected higher retail and energy revenue, acquisitions and a $127 million year-over-year improvement in net economic-hedge mark-to-market results. Q3 gross margin increased $204 million, but operating costs rose $312 million, including acquisition-related expenses, depreciation, maintenance and a $70 million impairment charge.
  • For the first nine months, improved gross margin included increases of $497 million in conventional generation, $202 million in renewables, $159 million in NRG Yield and $70 million in retail. Higher operating costs and a $95 million year-over-year deterioration in economic-hedge mark-to-market results partly offset that improvement.
  • Acquisitions and new projects substantially expanded the asset base and contributed to higher debt, depreciation and interest expense. EME contributed $703 million of revenue and $58 million of net income attributable to NRG since its acquisition date.

Outlook, commentary, risks and unusual items

  • Management stated that liquidity and operating cash flows were expected to be adequate for operations, maintenance capital expenditures, dividends and other commitments. The filing does not provide a clear quantified earnings or cash-flow forecast.
  • NRG estimated environmental capital expenditures of approximately $877 million for 2014–2018, including up to $350 million committed for plant modifications at Powerton and Joliet. The company also disclosed a $485 million guarantee of remaining lease payments through 2034 and approximately $490 million of assumed fuel and transportation commitments related to EME.
  • NRG recorded $60 million impairment for the Osceola gas facility, which it planned to mothball, and $10 million for solar panels. It also incurred $94 million of debt-extinguishment losses in the first nine months, primarily from redeeming higher-coupon 2019 notes.
  • A $614 million renewable-energy grant receivable included $539 million due under the federal cash-grant program and $75 million under a SunPower indemnity. Approximately $408 million of Ivanpah grant-bridge loans were due between December 2014 and April 2015; repayment depended on grant proceeds. NRG was pursuing a $75 million claim against SunPower.
  • Market risks include volatile power and fuel prices, counterparty credit exposure, collateral requirements, and interest-rate sensitivity. NRG reported $676 million net counterparty exposure after collateral, plus approximately $4.4 billion of modeled exposure under certain long-term agreements. It estimated a $267 million collateral change from a $0.50/MMBtu gas-price movement under marginable contracts.
  • Regulatory and environmental uncertainties include potential changes to PJM capacity markets, the demand-response ruling and possible market resettlement, CSAPR compliance expected to begin in January 2015, proposed emissions rules, and possible Maryland NOx requirements. The filing also describes ongoing legal proceedings and environmental matters; outcomes and costs are uncertain.
  • NRG disclosed that GenOn Mid-Atlantic and REMA failed restricted-payment tests and could not distribute cash as of September 30. S&P subsequently lowered ratings for GenOn-related entities on October 20, 2014. NRG’s overall risk factors were reported as unchanged from its 2013 Form 10-K.

Important facts for investors to verify

  • Whether acquisition-driven growth translates into sustainable operating cash flow and margins, apart from hedge mark-to-market effects.
  • The funding and repayment timing for the $408 million Ivanpah bridge loans and collection of the grant receivables, including the SunPower dispute.
  • Debt, interest expense, collateral needs and the availability of cash held at subsidiaries subject to distribution restrictions.
  • Actual environmental compliance costs, including the Powerton/Joliet commitment and the estimated $877 million 2014–2018 program.
  • Final purchase-price allocations for EME and Alta Wind, and the operating and financial performance of the acquired assets.