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Summary of Significant Accounting Policies | 6 Months Ended
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Jun. 30, 2018
Accounting Policies [Abstract] |
Summary of Significant Accounting Policies | Summary of Significant Accounting Policies Other Balance Sheet Information The following table presents the allowance for doubtful accounts included in accounts receivable, net; accumulated depreciation included in property, plant and equipment, net; accumulated amortization included in intangible assets, net and accumulated amortization included in out-of-market contracts, net:
| June 30, 2018 |  | December 31, 2017
| (In millions)
Accounts receivable allowance for doubtful accounts | $ | 28 |  |  | $ | 28 |
Property, plant and equipment accumulated depreciation | 4,534 |  |  | 4,465 |
Intangible assets accumulated amortization | 1,443 |  |  | 1,818 |
Out-of-market contracts accumulated amortization | 370 |  |  | 358 |
Restricted Cash The following table provides a reconciliation of cash and cash equivalents, restricted cash and funds deposited by counterparties reported within the consolidated balance sheet that sum to the total of the same such amounts shown in the statement of cash flows.
| June 30, 2018 |  | December 31, 2017 |  | June 30, 2017 |  | December 31, 2016
| (In millions)
Cash and cash equivalents | $ | 980 |  |  | $ | 991 |  |  | $ | 752 |  |  | $ | 938 |
Funds deposited by counterparties | 71 |  |  | 37 |  |  | 19 |  |  | 2 |
Restricted cash | 286 |  |  | 508 |  |  | 469 |  |  | 446 |
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statement of cash flows | $ | 1,337 |  |  | $ | 1,536 |  |  | $ | 1,240 |  |  | $ | 1,386 |
Funds deposited by counterparties consist of cash held by the Company as a result of collateral posting obligations from its counterparties. Some amounts are segregated into separate accounts that are not contractually restricted but, based on the Company's intention, are not available for the payment of general corporate obligations. Depending on market fluctuations and the settlement of the underlying contracts, the Company will refund this collateral to the hedge counterparties pursuant to the terms and conditions of the underlying trades. Since collateral requirements fluctuate daily and the Company cannot predict if any collateral will be held for more than twelve months, the funds deposited by counterparties are classified as a current asset on the Company's balance sheet, with an offsetting liability for this cash collateral received within current liabilities. Restricted cash consists primarily of funds held to satisfy the requirements of certain debt agreements and funds held within the Company's projects that are restricted in their use. Noncontrolling Interest The following table reflects the changes in NRG's noncontrolling interest balance:
| (In millions)
Balance as of December 31, 2017 | $ | 2,314 |
Dividends paid to NRG Yield, Inc. public shareholders | (61 | )
Distributions to noncontrolling interest | (34 | )
Comprehensive income attributable to noncontrolling interest | 12 |
Non-cash adjustments to noncontrolling interest | 8 |
Contributions from noncontrolling interest | 295 |
Sale of assets to NRG Yield, Inc. | (8 | )
Deconsolidation of Ivanpah(a) | (89 | )
Balance as of June 30, 2018 | $ | 2,437 |
(a) See Note 9, Variable Interest Entities, or VIEs for further information regarding the deconsolidation of Ivanpah effective April 2018. Redeemable Noncontrolling Interest The following table reflects the changes in the Company's redeemable noncontrolling interest balance:
| (In millions)
Balance as of December 31, 2017 | $ | 78 |
Distributions to redeemable noncontrolling interest | (2 | )
Contributions from redeemable noncontrolling interest | 26 |
Non-cash adjustments to redeemable noncontrolling interest | (9 | )
Comprehensive loss attributable to redeemable noncontrolling interest | (24 | )
Balance as of June 30, 2018 | $ | 69 |
Revenue Recognition Revenue from Contracts with Customers On January 1, 2018, the Company adopted the guidance in ASC 606 using the modified retrospective method applied to contracts which were not completed as of the adoption date. The Company recognized the cumulative effect of initially applying the new standard as a credit to the opening balance of accumulated deficit, resulting in a decrease of approximately $16 million. The adjustment primarily related to costs incurred to obtain a contract with customers and customer incentives. Following the adoption of the new standard, the Company’s revenue recognition of its contracts with customers remains materially consistent with its historical practice. The comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. The Company's policies with respect to its various revenue streams are detailed below. In general, the Company applies the invoicing practical expedient to recognize revenue for the revenue streams detailed below, except in circumstances where the invoiced amount does not represent the value transferred to the customer. Retail Revenues Gross revenues for energy sales and services to retail customers are recognized as the Company transfers the promised goods and services to the customer. For the majority of its electricity contracts, the Company’s performance obligation with the customer is satisfied over time and performance obligations for its electricity products are recognized as the customer takes possession of the product. The Company also allocates the contract consideration to distinct performance obligation in a contract for which the timing of the revenue recognized is different. Additionally, customer discounts and incentives reduce the contract consideration and are recognized over the term of the contract. Energy sales and services that have been delivered but not billed by period end are estimated. Accrued unbilled revenues are based on estimates of customer usage since the date of the last meter reading provided by the independent system operators or electric distribution companies. Volume estimates are based on daily forecasted volumes and estimated customer usage by class. Unbilled revenues are calculated by multiplying these volume estimates by the applicable rate by customer class. Estimated amounts are adjusted when actual usage is known and billed. As contracts for retail electricity can be for multi-year periods, the Company has performance obligations under these contracts that have not yet been satisfied. These performance obligations have transaction prices that are both fixed and variable, and that vary based on the contract duration, customer type, inception date and other contract-specific factors. For the fixed price contracts, the amount of any unsatisfied performance obligations will vary based on customer usage, which will depend on factors such as weather and customer activity and therefore it is not practicable to estimate such amounts. Energy Revenue Both physical and financial transactions are entered into to optimize the financial performance of the Company's generating facilities. Electric energy revenue is recognized upon transmission to the customer over time, using the output method for measuring progress of satisfaction of performance obligations. Physical transactions, or the sale of generated electricity to meet supply and demand, are recorded on a gross basis in the Company's consolidated statements of operations. The Company applies the invoicing practical expedient, where applicable, in recognizing energy revenue. Under the practical expedient, revenue is recognized based on the invoiced amount which is equal to the value to the customer of NRG’s performance obligation completed to date. Financial transactions, or the buying and selling of energy for trading purposes, are recorded net within operating revenues in the consolidated statements of operations in accordance with ASC 815. Capacity Revenue Capacity revenues consist of revenues billed to a third party at either the market or a negotiated contract price for making installed generation capacity available in order to satisfy system integrity and reliability requirements. Capacity revenues are recognized over time, using the output method for measuring progress of satisfaction of performance obligations. The Company applies the invoicing practical expedient, where applicable, in recognizing capacity revenue. Under the practical expedient, revenue is recognized based on the invoiced amount which is equal to the value to the customer of NRG’s performance obligation completed to date. Capacity revenue contracts mainly consist of: Capacity auctions — The Company's largest sources of capacity revenues are capacity auctions in PJM, ISO-NE, and NYISO. Both ISO-NE and PJM operate a pay-for-performance model where capacity payments are modified based on real-time performance, where NRG's actual revenues will be the combination of revenues based on the cleared auction MWs plus the net of any over- and under-performance of NRG's fleet. In addition, MISO has an annual auction, known as the Planning Resource Auction, or PRA. The Gulf Coast assets situated in the MISO market may participate in this auction. Estimated revenues for cleared auction MWs in the various capacity auctions are $578 million, $519 million, $410 million, $388 million and $168 million for fiscal years 2018, 2019, 2020, 2021 and 2022, respectively. Resource adequacy and bilateral contracts — In California, there is a resource adequacy requirement that is primarily satisfied through bilateral contracts. Such bilateral contracts are typically short-term resource adequacy contracts. When bilateral contracting does not satisfy the resource adequacy need, such shortfalls can be addressed through procurement tools administered by the CAISO, including the capacity procurement mechanism or reliability must-run contracts. Demand payments from the current long-term contracts are tied to summer peak demand and provide a mechanism for recovering a portion of the costs associated with new or changed environmental laws or regulations. In Texas, capacity and contracted revenues are through bilateral contracts with load serving entities. Long-term PPAs — Energy, capacity and where applicable, renewable attributes, from the majority of renewable energy assets and certain conventional energy plants is sold through long-term PPAs and tolling agreements to a single counterparty, which is often a utility or commercial customer. Many of these PPAs are accounted for as leases. Renewable Energy Credits As stated above, renewable energy credits are usually sold through long-term PPAs. Revenue from the sale of self-generated RECs is recognized when related energy is generated and simultaneously delivered even in cases where there is a certification lag as it has been deemed to be perfunctory. In a bundled contract to sell energy, capacity and/or self-generated RECs, all performance obligations are deemed to be delivered at the same time and hence, timing of recognition of revenue for all performance obligations is the same and occurs over time. In such cases, it is often unnecessary to allocate transaction price to multiple performance obligations. Sale of Emission Allowances The Company records its inventory of emission allowances as part of intangible assets. From time to time, management may authorize the transfer of emission allowances in excess of usage from the Company's emission bank to intangible assets held-for-sale for trading purposes. The Company records the sale of emission allowances on a net basis within operating revenue in the Company's consolidated statements of operations. Disaggregated Revenues The following table represents the Company’s disaggregation of revenue from contracts with customers for the three and six months ended June 30, 2018, along with the reportable segment for each category:
| Three months ended June 30, 2018
|  |  | Generation |  |  |  |  |  |  |  |
(In millions) | Retail |  | Gulf Coast |  | East/West |  | Subtotal |  | Renewables |  | NRG Yield |  | Eliminations |  | Total
Energy revenue(a)(b) | $ | — |  |  | $ | 508 |  |  | $ | 144 |  |  | $ | 652 |  |  | $ | 79 |  |  | $ | 192 |  |  | $ | (250 | ) |  | $ | 673 |
Capacity revenue(a)(b) | — |  |  | 68 |  |  | 160 |  |  | 228 |  |  | — |  |  | 87 |  |  | (2 | ) |  | 313 |
Retail revenue |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Mass customers | 1,380 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (1 | ) |  | 1,379 |
Business solutions customers | 437 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 437 |
Total retail revenue | 1,817 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (1 | ) |  | 1,816 |
Mark-to-market for economic hedging activities(c) | — |  |  | 289 |  |  | (15 | ) |  | 274 |  |  | 5 |  |  | — |  |  | (264 | ) |  | 15 |
Contract amortization | — |  |  | 4 |  |  | — |  |  | 4 |  |  | — |  |  | (18 | ) |  | — |  |  | (14 | )
Other revenue(a)(b) | — |  |  | 42 |  |  | 18 |  |  | 60 |  |  | 29 |  |  | 46 |  |  | (16 | ) |  | 119 |
Total operating revenue | 1,817 |  |  | 911 |  |  | 307 |  |  | 1,218 |  |  | 113 |  |  | 307 |  |  | (533 | ) |  | 2,922 |
Less: Lease revenue | 6 |  |  | — |  |  | 1 |  |  | 1 |  |  | 96 |  |  | 267 |  |  | — |  |  | 370 |
Less: Derivative revenue | — |  |  | 898 |  |  | (1 | ) |  | 897 |  |  | 5 |  |  | — |  |  | (264 | ) |  | 638 |
Less: Contract amortization | — |  |  | 4 |  |  | — |  |  | 4 |  |  | — |  |  | (18 | ) |  | — |  |  | (14 | )
Total revenue from contracts with customers | $ | 1,811 |  |  | $ | 9 |  |  | $ | 307 |  |  | $ | 316 |  |  | $ | 12 |  |  | $ | 58 |  |  | $ | (269 | ) |  | $ | 1,928 |
(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 840:
| Retail |  | Gulf Coast |  | East/West |  | Subtotal |  | Renewables |  | NRG Yield |  | Eliminations |  | Total
Energy revenue | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 90 |  |  | $ | 182 |  |  | $ | — |  |  | $ | 272 |
Capacity revenue | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 85 |  |  | — |  |  | 85 |
Other revenue | 6 |  |  | — |  |  | 1 |  |  | 1 |  |  | 6 |  |  | — |  |  | — |  |  | 13 |
(b) The following amounts of energy and capacity revenue relate to derivative instruments and are accounted for under ASC 815.
| Retail |  | Gulf Coast |  | East/West |  | Subtotal |  | Renewables |  | NRG Yield |  | Eliminations |  | Total
Energy revenue | $ | — |  |  | $ | 610 |  |  | $ | (30 | ) |  | $ | 580 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 580 |
Capacity revenue | — |  |  | — |  |  | 39 |  |  | 39 |  |  | — |  |  | — |  |  | — |  |  | 39 |
Other revenue | — |  |  | (1 | ) |  | 5 |  |  | 4 |  |  | — |  |  | — |  |  | — |  |  | 4 |
(c) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815.
| Six months ended June 30, 2018
|  |  | Generation |  |  |  |  |  |  |  |
(In millions) | Retail |  | Gulf Coast |  | East/West |  | Subtotal |  | Renewables |  | NRG Yield |  | Eliminations |  | Total
Energy revenue(a)(b) | $ | — |  |  | $ | 879 |  |  | $ | 362 |  |  | $ | 1,241 |  |  | $ | 156 |  |  | $ | 306 |  |  | $ | (411 | ) |  | $ | 1,292 |
Capacity revenue(a)(b) | — |  |  | 135 |  |  | 300 |  |  | 435 |  |  | — |  |  | 169 |  |  | (3 | ) |  | 601 |
Retail revenue |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Mass customers | 2,551 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (2 | ) |  | 2,549 |
Business solutions customers | 753 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 753 |
Total retail revenue | 3,304 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (2 | ) |  | 3,302 |
Mark-to-market for economic hedging activities(c) | (6 | ) |  | (275 | ) |  | (25 | ) |  | (300 | ) |  | (5 | ) |  | — |  |  | 220 |  |  | (91 | )
Contract amortization | — |  |  | 7 |  |  | — |  |  | 7 |  |  | — |  |  | (35 | ) |  | — |  |  | (28 | )
Other revenue(a)(b) | — |  |  | 128 |  |  | 34 |  |  | 162 |  |  | 48 |  |  | 92 |  |  | (35 | ) |  | 267 |
Total operating revenue | 3,298 |  |  | 874 |  |  | 671 |  |  | 1,545 |  |  | 199 |  |  | 532 |  |  | (231 | ) |  | 5,343 |
Less: Lease revenue | 12 |  |  | — |  |  | 2 |  |  | 2 |  |  | 160 |  |  | 448 |  |  | — |  |  | 622 |
Less: Derivative revenue | (6 | ) |  | 710 |  |  | 79 |  |  | 789 |  |  | (5 | ) |  | — |  |  | 220 |  |  | 998 |
Less: Contract amortization | — |  |  | 7 |  |  | — |  |  | 7 |  |  | — |  |  | (35 | ) |  | — |  |  | (28 | )
Total revenue from contracts with customers | $ | 3,292 |  |  | $ | 157 |  |  | $ | 590 |  |  | $ | 747 |  |  | $ | 44 |  |  | $ | 119 |  |  | $ | (451 | ) |  | $ | 3,751 |
(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 840:
| Retail |  | Gulf Coast |  | East/West |  | Subtotal |  | Renewables |  | NRG Yield |  | Eliminations |  | Total
Energy revenue | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 151 |  |  | $ | 284 |  |  | $ | — |  |  | $ | 435 |
Capacity revenue | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 164 |  |  | — |  |  | 164 |
Other revenue | 12 |  |  | — |  |  | 2 |  |  | 2 |  |  | 9 |  |  | — |  |  | — |  |  | 23 |
(b) The following amounts of energy and capacity revenue relate to derivative instruments and are accounted for under ASC 815.
| Retail |  | Gulf Coast |  | East/West |  | Subtotal |  | Renewables |  | NRG Yield |  | Eliminations |  | Total
Energy revenue | $ | — |  |  | $ | 981 |  |  | $ | 31 |  |  | $ | 1,012 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 1,012 |
Capacity revenue | — |  |  | — |  |  | 65 |  |  | 65 |  |  | — |  |  | — |  |  | — |  |  | 65 |
Other revenue | — |  |  | 4 |  |  | 8 |  |  | 12 |  |  | — |  |  | — |  |  | — |  |  | 12 |
(c) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815.
Contract Amortization Assets and liabilities recognized from power sales agreements assumed at Fresh Start and through acquisitions related to the sale of electric capacity and energy in future periods for which the fair value has been determined to be significantly less (more) than market are amortized to revenue over the term of each underlying contract based on actual generation and/or contracted volumes. Lease Revenue Certain of the Company’s revenues are obtained through PPAs or other contractual agreements. Many of these agreements are accounted for as operating leases under ASC 840 Leases. Certain of these leases have no minimum lease payments and all of the rent is recorded as contingent rent on an actual basis when the electricity is delivered. Judgment is required by management in determining the economic life of each generating facility, in evaluating whether certain lease provisions constitute minimum payments or represent contingent rent and other factors in determining whether a contract contains a lease and whether the lease is an operating lease or capital lease. Contract Balances The following table reflects the contract assets and liabilities included in the Company’s balance sheet as of June 30, 2018:
(In millions) |  | June 30, 2018
Deferred customer acquisition costs |  | $ | 102 |
Accounts receivable, net - Contracts with customers |  | 1,187 |
Accounts receivable, net - Leases |  | 152 |
Accounts receivable, net - Derivative instruments |  | 32 |
Total accounts receivable, net |  | $ | 1,371 |
Unbilled revenues (included within Accounts receivable, net - Contracts with customers) |  | 445 |
Deferred revenues |  | 73 |
The Company’s customer acquisition costs consist of broker fees, commission payments and other costs that represent incremental costs of obtaining the contract with customers for which the Company expects to recover. The Company amortizes these amounts over the estimated life of the customer contract. As a practical expedient, the Company expenses the incremental costs of obtaining a contract if the amortization period of the asset would have been one year or less. When the Company receives consideration from the customer that is in excess of the amount due, such consideration is reclassified to deferred revenue, which represents a contract liability. Generally, the Company will recognize revenue from contract liabilities in the next period as the Company satisfies its performance obligations. Recent Accounting Developments - Guidance Adopted in 2018 ASU 2017-07 — In March 2017, the FASB issued ASU No. 2017-07, Compensation - Retirement Benefits (Topic 715), Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost, or ASU No. 2017-07. Current GAAP does not indicate where the amount of net benefit cost should be presented in an entity’s income statement and does not require entities to disclose the amount of net benefit cost that is included in the income statement. The amendments of ASU No. 2017-07 require an entity to report the service cost component of net benefit costs in the same line item as other compensation costs arising from services rendered by the related employees during the applicable service period. The other components of net benefit cost are required to be presented separately from the service cost component and outside the subtotal of income from operations. Further, ASU No. 2017-07 prescribes that only the service cost component of net benefit costs is eligible for capitalization. The Company adopted the amendments of ASU No. 2017-07 effective January 1, 2018. In connection with the adoption of the standard, the Company has applied the guidance retrospectively which resulted in an increase in cost of operations of $4 million and $8 million with a corresponding increase in other income, net on the statement of operations for the three and six months ended June 30, 2017, respectively. ASU 2016-01 - In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities, or ASU No. 2016-01. The amendments of ASU No. 2016-01 eliminate available-for-sale classification of equity investments and require that equity investments (except those accounted for under the equity method of accounting, or those that result in consolidation of the investee) be generally measured at fair value with changes in fair value recognized in net income. Further, the amendments require that financial assets and financial liabilities be presented separately in the notes to the financial statements, grouped by measurement category and form of financial asset. The guidance in ASU No. 2016-01 is effective for financial statements issued for fiscal years beginning after December 15, 2017, and interim periods within those annual periods. The Company adopted the amendments of ASU No. 2016-01 effective January 1, 2018. In connection with the adoption of the standard, the Company has applied the guidance on a modified retrospective basis, which resulted in no material adjustments recorded to the consolidated results of operations, cash flows, and statement of financial position. Recent Accounting Developments - Guidance Not Yet Adopted ASU 2016-02 — In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), or Topic 842, with the objective to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and to improve financial reporting by expanding the related disclosures. The guidance in Topic 842 provides that a lessee that may have previously accounted for a lease as an operating lease under current GAAP should recognize the assets and liabilities that arise from a lease on the balance sheet. In addition, Topic 842 expands the required quantitative and qualitative disclosures with regards to lease arrangements. The Company will adopt the standard effective January 1, 2019, and expects to elect certain of the practical expedients permitted, including the expedient that permits the Company to retain its existing lease assessment and classification. The Company is currently working through an adoption plan which includes the evaluation of lease contracts compared to the new standard. While the Company is currently evaluating the impact the new guidance will have on its financial position and results of operations, the Company expects to recognize lease liabilities and right of use assets. The extent of the increase to assets and liabilities associated with these amounts remains to be determined pending the Company’s review of its existing lease contracts and service contracts which may contain embedded leases. While this review is still in process, NRG believes the adoption of Topic 842 will have a material impact on its financial statements. The Company is also monitoring recent changes to Topic 842 and the related impact on the implementation process.

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