NRG ENERGY, INC. quarterly report, Q1 FY2021

NRG Energy, Inc. — Q1 2021 Form 10-Q

Reporting period: Three months ended March 31, 2021. NRG is an integrated U.S. and Canadian power company with retail energy operations and approximately 23,000 MW of generation. The period includes Direct Energy from its January 5 acquisition; accordingly, year-over-year comparisons are not directly comparable.

Key financial results

Metric	Q1 2021	Q1 2020
Operating revenue	$8.091 billion	$2.019 billion
Operating income (loss)	$(56) million	$244 million
Net income (loss)	$(82) million	$121 million
Diluted earnings (loss) per share	$(0.33)	$0.49
Cash from (used in) operating activities	$(917) million	$208 million

• Revenue rose by $6.072 billion, primarily reflecting Direct Energy’s contribution of $4.161 billion and unusually high Texas ancillary revenue during Winter Storm Uri. The acquired business contributed $134 million of pretax income.
• Gross margin was $1.660 billion versus $917 million; economic gross margin, a non-GAAP measure, was $940 million versus $874 million. Q1 2021 results included $725 million of unrealized derivative gains, making reported results sensitive to mark-to-market movements.
• Uri reduced pretax income by an estimated $967 million: $361 million lower gross margin, $585 million in credit-loss provisions, and $21 million of higher SG&A. The credit-loss provision included $393 million for a bilateral hedge counterparty default, $109 million of other counterparty credit risk, and $83 million of ERCOT shortfall payments.
• Cash used in operations was driven in part by working-capital needs: accounts receivable increased primarily due to Uri. Investing cash outflow was $3.364 billion, including $3.482 billion paid for Direct Energy, partly offset by $197 million of asset-sale proceeds. Financing provided $924 million.
• At March 31, cash and cash equivalents were $501 million, down from $3.905 billion at year-end. Total liquidity, excluding counterparty deposits, was $3.243 billion, including $2.724 billion of availability under the revolving credit and collateral facilities.
• Long-term debt and finance leases totaled $9.696 billion before debt issuance costs, discounts and current maturities; the balance-sheet carrying amount of debt and leases, including current maturities, was approximately $9.536 billion. NRG had $750 million drawn on its $3.7 billion revolving credit facility at quarter-end. Interest expense was $127 million, up from $98 million.
• The company recorded an $85 million income tax benefit on a $167 million pretax loss; the reported effective tax rate was 50.9%.

Material changes and significant events

• NRG acquired Direct Energy for a stated aggregate cash purchase price of $3.625 billion, plus purchase-price adjustments. The acquisition added more than 3 million retail customers, expanded geographic reach, and contributed materially to the larger balance sheet, revenue and operating costs. Purchase accounting remained provisional.
• NRG agreed to sell approximately 4,850 MW of East and West fossil generation assets for $760 million, subject to adjustments, approvals and other closing conditions; closing was expected in Q4 2021. The company also agreed to a tolling arrangement for the 866 MW Arthur Kill plant through April 2025.
• NRG sold its 35% interest in the Agua Caliente solar project for $202 million and recorded a $17 million gain.
• Winter Storm Uri drove extreme ERCOT prices and operating disruption. Average on-peak ERCOT prices reported for Q1 were about $620/MWh, compared with approximately $24–$25/MWh a year earlier. NRG’s East segment benefited from gas optimization during the storm, while Texas results were sharply adversely affected.

Outlook, risks and contingencies

• Management said liquidity and operating cash flows were expected to support operations, maintenance capital expenditures, dividends and other commitments. NRG did not provide a clear company-wide earnings forecast in the supplied filing text.
• Following Uri, the planned debt-reduction program was extended into 2022. Management said it remained committed to a strong balance sheet and was working with rating agencies; S&P placed its BB+ rating on CreditWatch with negative implications, while Moody’s affirmed Ba1 and changed its outlook to stable.
• NRG targeted annual dividend growth of 7%–9% in subsequent years. The annualized dividend was increased to $1.30 per share; the Q1 quarterly dividend was $0.325 per share. Dividends remain subject to capital availability, market conditions and contractual requirements.
• ERCOT defaults and potential market-rule changes remain material uncertainties. NRG reported $83 million of ERCOT shortfall payments and estimated its undiscounted share of potential market uplift at approximately $185 million; it recorded a $12 million liability based on the present value of the remaining estimated amount under then-current rules. Legislative securitization proposals and possible changes to storm-period settlements could affect the eventual outcome.
• NRG said recovery of the $393 million bilateral hedge-counterparty exposure from Uri was uncertain and recorded the full amount as a credit-loss provision. Uri-related customer, counterparty, settlement and litigation exposures could change as information develops.
• Other risks include volatile power and gas prices, collateral demands, Direct Energy integration, regulatory and environmental changes, and pending legal matters. Environmental compliance capital spending was estimated at $63 million for 2021–2025; certain coal-unit compliance costs were not yet estimable.

Important facts for investors to verify

• How much of reported revenue and margin growth reflects Direct Energy, storm-related activity, and unrealized derivative gains rather than recurring operating performance.
• Final ERCOT settlement and uplift amounts, recovery on the bilateral counterparty exposure, and effects of Texas legislative or regulatory action.
• Direct Energy integration progress, final acquisition accounting and purchase-price adjustment, and whether anticipated synergies are realized.
• Completion, proceeds and any material conditions or adjustments for the planned fossil-asset sale.
• Liquidity, collateral requirements and debt-reduction progress, especially under adverse commodity-price or credit-rating scenarios.
• Dividend growth capacity and eventual environmental compliance costs.