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Summary of Significant Accounting and Reporting Policies (Policies) | 12 Months Ended
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Dec. 31, 2019
Accounting Policies [Abstract] |
Basis of Presentation | Basis of Presentation - The operations of NextEra Energy, Inc. (NEE) are conducted primarily through Florida Power & Light Company (FPL), a wholly owned subsidiary, and NextEra Energy Resources, LLC (NextEra Energy Resources) and NextEra Energy Transmission, LLC (NEET) (collectively, NEER), wholly owned indirect subsidiaries that are combined for segment reporting purposes. FPL's principal business is a rate-regulated electric utility which supplies electric service to more than five million customer accounts throughout most of the east and lower west coasts of Florida. NEER invests in independent power projects through both controlled and consolidated entities and noncontrolling ownership interests in joint ventures. NEER participates in natural gas, natural gas liquids and oil production primarily through operating and non-operating ownership interests and in pipeline infrastructure through either wholly owned subsidiaries or noncontrolling or joint venture interests. NEER also invests in rate-regulated transmission facilities and transmission lines that connect its electric generation facilities to the electric grid through controlled and consolidated entities. See Note 16 for a discussion of the movement of NEET to the NEER segment from Corporate and Other. The consolidated financial statements of NEE and FPL include the accounts of their respective controlled subsidiaries. They also include NEE's and FPL's share of the undivided interest in certain assets, liabilities, revenues and expenses. Amounts representing NEE's interest in entities it does not control, but over which it exercises significant influence, are included in investment in equity method investees; the net income of these entities is included in equity in earnings of equity method investees. Intercompany balances and transactions have been eliminated in consolidation. Certain amounts included in prior years' consolidated financial statements have been reclassified to conform to the current year's presentation. The preparation of financial statements requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ from those estimates.
NextEra Energy Partners, LP | NextEra Energy Partners, LP - NEP was formed in 2014 to acquire, manage and own contracted clean energy projects with stable long-term cash flows through a limited partner interest in NextEra Energy Operating Partners, LP (NEP OpCo). NEP owns or has an interest in a portfolio of wind and solar projects and long-term contracted natural gas pipelines. NEP was deconsolidated from NEE for financial reporting purposes in January 2018 as a result of changes made to NEP's governance structure during 2017 that, among other things, enhanced NEP common unitholder governance rights. The new governance structure established a NEP board of directors whereby NEP unitholders have the ability to nominate and elect board members, subject to certain limitations and requirements, which elected board members commenced service in January 2018. Subsequent to deconsolidation, NEE owns a noncontrolling interest in NEP and began reflecting its ownership interest in NEP as an equity method investment with its earnings/losses from NEP as equity in earnings (losses) of equity method investees and accounting for NextEra Energy Resources' asset sales to NEP as third-party sales in its consolidated financial statements. NEER continues to operate the projects owned by NEP and provide services to NEP under various related party operations and maintenance, administrative and management services agreements. In connection with the deconsolidation, NEE recorded an initial investment in NEP of approximately $4.4 billion based on the fair value of NEP OpCo and NEP common units that were held by subsidiaries of NEE on the deconsolidation date, which investment is included in the investment in equity method investees on NEE's consolidated balance sheets. See Note 10. The fair value was based on the market price of NEP common units as of January 1, 2018, which resulted in NEE recording a gain of approximately $3.9 billion ($3.0 billion after tax) for the year ended December 31, 2018. Prior to the deconsolidation, NEE owned a controlling general partner interest in NEP and consolidated NEP for financial reporting purposes. NEE presented its limited partner interests in NEP as a noncontrolling interest in NEE's consolidated financial statements. NEE’s partnership interest in NEP OpCo's operating projects based on the number of outstanding NEP OpCo common units was approximately 65.1% at December 31, 2017. Certain equity and asset transactions between NEP, NEER and NEP OpCo involve the exchange of cash, energy projects and ownership interests in NEP OpCo.
Operating Revenues | Operating Revenues - FPL and NEER generate substantially all of NEE’s operating revenues, which primarily include revenues from contracts with customers as further discussed in Note 2, as well as, at NEER, derivative and lease transactions. FPL's operating revenues include amounts resulting from base rates, cost recovery clauses (see Rate Regulation below), franchise fees, gross receipts taxes and surcharges related to storms (see Storm Fund, Storm Reserve and Storm Cost Recovery below). Franchise fees and gross receipts taxes are imposed on FPL; however, the Florida Public Service Commission (FPSC) allows FPL to include in the amounts charged to customers the amount of the gross receipts tax for all customers and the franchise fee for those customers located in the jurisdiction that imposes the amount. Accordingly, franchise fees and gross receipts taxes are reported gross in operating revenues and taxes other than income taxes and other in NEE's and FPL's consolidated statements of income and were approximately $763 million, $738 million and $767 million in 2019, 2018 and 2017, respectively. FPL also collects municipal utility taxes which are reported gross in customer receivables and accounts payable on NEE's and FPL's consolidated balance sheets. Certain NEER commodity contracts for the purchase and sale of power that meet the definition of a derivative are recorded at fair value with subsequent changes in fair value recognized as revenue. See Energy Trading below and Note 4.
Rate Regulation | Rate Regulation - FPL, the most significant of NEE's rate-regulated subsidiaries, is subject to rate regulation by the FPSC and the Federal Energy Regulatory Commission (FERC). Its rates are designed to recover the cost of providing service to its customers including a reasonable rate of return on invested capital. As a result of this cost-based regulation, FPL follows the accounting guidance that allows regulators to create assets and impose liabilities that would not be recorded by non-rate regulated entities. Regulatory assets and liabilities represent probable future revenues that will be recovered from or refunded to customers through the ratemaking process. NEE's and FPL's regulatory assets and liabilities are as follows:
| NEE |  | FPL
| December 31, |  | December 31,
| 2019 |  | 2018 |  | 2019 |  | 2018
| (millions)
Regulatory assets: |  |  |  |  |  |  |
Current: |  |  |  |  |  |  |
Acquisition of purchased power agreements | $ | 165 |  |  | $ | 165 |  |  | $ | 165 |  |  | $ | 165 |
Deferred clause and franchise expenses | 5 |  |  | 146 |  |  | 5 |  |  | 146 |
Other | 165 |  |  | 137 |  |  | 57 |  |  | 136 |
Total | $ | 335 |  |  | $ | 448 |  |  | $ | 227 |  |  | $ | 447 |
Noncurrent: |  |  |  |  |  |  |  |  |  |  |
Acquisition of purchased power agreements | $ | 634 |  |  | $ | 798 |  |  | $ | 634 |  |  | $ | 798 |
Other | 2,653 |  |  | 2,492 |  |  | 1,915 |  |  | 2,045 |
Total | $ | 3,287 |  |  | $ | 3,290 |  |  | $ | 2,549 |  |  | $ | 2,843 |
Regulatory liabilities: |  |  |  |  |  |  |  |  |  |  |
Current: |  |  |  |  |  |  |
Deferred clause revenues | $ | 309 |  |  | $ | 265 |  |  | $ | 284 |  |  | $ | 265 |
Other | 11 |  |  | 60 |  |  | — |  |  | 45 |
Total | $ | 320 |  |  | $ | 325 |  |  | $ | 284 |  |  | $ | 310 |
Noncurrent: |  |  |  |  |  |  |  |  |  |  |
Asset retirement obligation regulatory expense difference | $ | 2,826 |  |  | $ | 2,352 |  |  | $ | 2,828 |  |  | $ | 2,352 |
Accrued asset removal costs | 1,346 |  |  | 991 |  |  | 1,157 |  |  | 972 |
Deferred taxes | 4,862 |  |  | 4,815 |  |  | 4,397 |  |  | 4,736 |
Other | 902 |  |  | 851 |  |  | 914 |  |  | 826 |
Total | $ | 9,936 |  |  | $ | 9,009 |  |  | $ | 9,296 |  |  | $ | 8,886 |
Cost recovery clauses, which are designed to permit full recovery of certain costs and provide a return on certain assets allowed to be recovered through various clauses, include substantially all fuel, purchased power and interchange expense, certain costs associated with the acquisition of several electric generation facilities, certain construction-related costs for certain of FPL's solar generation facilities, and conservation and certain environmental-related costs. Revenues from cost recovery clauses are recorded when billed; FPL achieves matching of costs and related revenues by deferring the net underrecovery or overrecovery. Any underrecovered costs or overrecovered revenues are collected from or returned to customers in subsequent periods. At December 31, 2019 and 2018, FPL had regulatory assets, net of amortization, of approximately $799 million and $963 million, respectively, (included in current and noncurrent regulatory assets on NEE's and FPL’s consolidated balance sheets) related to acquisitions during 2015, 2017 and 2018 associated with three coal-fired electric generation facilities located in Florida with which FPL had long-term purchased power agreements. The majority of these regulatory assets are being amortized over approximately nine years. Two of the three facilities have been retired and FPL has reduced the third facility’s operations with the intention of phasing the facility out of service. In 2018, FPL early retired three of its generation facilities. As a result of the retirements, FPL reclassified the net book value of these units (approximately $875 million) from plant in service and other property to current and noncurrent regulatory assets. Recovery of $729 million of these regulatory assets has been deferred until FPL’s base rates are next reset in a general base rate proceeding. The remainder of these regulatory assets are being amortized over 15 years. At December 31, 2019 and 2018, the regulatory assets, net of amortization, totaled approximately $851 million and $870 million, respectively, and are included in current and noncurrent regulatory assets on NEE's and FPL's consolidated balance sheets. Additionally, other regulatory assets and liabilities are discussed within various subsections in Note 1 below. If FPL were no longer subject to cost-based rate regulation, the existing regulatory assets and liabilities would be written off unless regulators specify an alternative means of recovery or refund. In addition, the FPSC has the authority to disallow recovery of costs that it considers excessive or imprudently incurred. The continued applicability of regulatory accounting is assessed at each reporting period.
Electric Plant, Depreciation and Amortization | Electric Plant, Depreciation and Amortization - The cost of additions to units of property of FPL and NEER is added to electric plant in service and other property. In accordance with regulatory accounting, the cost of FPL's units of utility property retired, less estimated net salvage value, is charged to accumulated depreciation. Maintenance and repairs of property as well as replacements and renewals of items determined to be less than units of utility property are charged to other operations and maintenance (O&M) expenses. At December 31, 2019, the electric generation, transmission, distribution and general facilities of FPL represented approximately 46%, 12%, 35% and 7%, respectively, of FPL's gross investment in electric utility plant in service and other property. Substantially all of FPL's properties are subject to the lien of FPL's mortgage, which secures most debt securities issued by FPL. A number of NEER's generation, regulated transmission and pipeline facilities are encumbered by liens securing various financings. The net book value of NEER's assets serving as collateral was approximately $10.0 billion at December 31, 2019. The American Recovery and Reinvestment Act of 2009, as amended (Recovery Act), provided for an option to elect a cash grant (convertible investment tax credits (ITCs)) for certain renewable energy property (renewable property). Convertible ITCs are recorded as a reduction in property, plant and equipment on NEE's and FPL's consolidated balance sheets and are amortized as a reduction to depreciation and amortization expense over the estimated life of the related property. At December 31, 2019 and 2018, convertible ITCs, net of amortization, were approximately $824 million ($128 million at FPL) and $1.2 billion ($134 million at FPL). At December 31, 2019 and 2018, approximately $10 million and $138 million, respectively, of such convertible ITCs are included primarily in other receivables on NEE's consolidated balance sheets. Depreciation of FPL's electric property is primarily provided on a straight-line average remaining life basis. FPL includes in depreciation expense a provision for fossil and solar plant dismantlement, interim asset removal costs, accretion related to asset retirement obligations (see Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below), storm recovery amortization and amortization of pre-construction costs associated with planned nuclear units recovered through a cost recovery clause. For substantially all of FPL's property, depreciation studies are typically performed and filed with the FPSC every four years. As part of the 2016 rate agreement, the FPSC approved new depreciation rates which became effective January 1, 2017. In accordance with the 2016 rate agreement discussed in Rate Regulation above, FPL recorded reserve amortization (reversal) of approximately $(357) million, $(541) million and $1,250 million in 2019, 2018 and 2017, respectively. Reserve amortization is recorded as a reduction to (or when reversed as an increase to) accrued asset removal costs which is reflected in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. In 2017, FPL used available reserve amortization to offset nearly all of the Hurricane Irma storm restoration costs that were expensed, and FPL is partially restoring the reserve amortization through tax savings generated during the term of the 2016 rate agreement. See Note 6. In 2019, FPL used available reserve amortization resulting from operational efficiencies generated at the business to offset all of the Hurricane Dorian storm restoration costs that were expensed. See Storm Fund, Storm Reserve and Storm Restoration Costs below. The weighted annual composite depreciation and amortization rate for FPL's electric utility plant in service, including capitalized software, but excluding the effects of decommissioning, dismantlement and the depreciation adjustments discussed above, was approximately 3.9%, 3.8% and 3.7% for 2019, 2018 and 2017, respectively. FPL files a twelve-month forecast with the FPSC each year which contains a regulatory ROE intended to be earned based on the best information FPL has at that time assuming normal weather. This forecast establishes a fixed targeted regulatory ROE. In order to earn the targeted regulatory ROE in each reporting period under the 2016 rate agreement, reserve amortization is calculated using a trailing thirteen-month average of retail rate base and capital structure in conjunction with the trailing twelve months regulatory retail base net operating income, which primarily includes the retail base portion of base and other revenues, net of O&M, depreciation and amortization, interest and tax expenses. In general, the net impact of these income statement line items is adjusted, in part, by reserve amortization or its reversal to earn the targeted regulatory ROE. NEER's electric plant in service less salvage value, if any, are depreciated primarily using the straight-line method over their estimated useful lives. At December 31, 2019, wind, solar and nuclear plants represented approximately 54%, 12% and 10%, respectively, of NEER's depreciable electric plant in service and other property; the respective amounts at December 31, 2018 were 53%, 14% and 10%. The estimated useful lives of NEER's plants range primarily from 25 to 35 years for wind plants, 25 to 30 years for solar plants and 23 to 47 years for nuclear plants (see Note 5 - Nonrecurring Fair Value Measurements). NEER reviews the estimated useful lives of its fixed assets on an ongoing basis. NEER's oil and gas production assets, representing approximately 15% and 13%, respectively, of NEER's depreciable electric plant in service and other property at December 31, 2019 and 2018, are accounted for under the successful efforts method. Depletion expenses for the acquisition of reserve rights and development costs are recognized using the unit of production method.
Nuclear Fuel | Nuclear Fuel - FPL and NEER have several contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel. See Note 15 - Contracts. FPL's and NEER's nuclear fuel costs are charged to fuel expense on a unit of production method.
Construction Activity | Construction Activity - Allowance for funds used during construction (AFUDC) is a noncash item which represents the allowed cost of capital, including an ROE, used to finance construction projects. FPL records the portion of AFUDC attributable to borrowed funds as a reduction of interest expense and the remainder as other income. FPSC rules limit the recording of AFUDC to projects that have an estimated cost in excess of 0.5% of a utility's plant in service balance and require more than one year to complete. FPSC rules allow construction projects below the 0.5% threshold as a component of rate base. During 2019, 2018 and 2017, FPL capitalized AFUDC at a rate of 6.22%, 5.97% and 6.16%, respectively, which amounted to approximately $80 million, $114 million and $101 million, respectively. See Note 15 - Commitments. FPL's construction work in progress includes construction materials, progress payments on major equipment contracts, engineering costs, AFUDC and other costs directly associated with the construction of various projects. Upon completion of the projects, these costs are transferred to electric utility plant in service and other property. Capitalized costs associated with construction activities are charged to O&M expenses when recoverability is no longer probable. NEER capitalizes project development costs once it is probable that such costs will be realized through the ultimate construction of a power plant or sale of development rights. At December 31, 2019 and 2018, NEER's capitalized development costs totaled approximately $651 million and $630 million, respectively, which are included in noncurrent other assets on NEE's consolidated balance sheets. These costs include land rights and other third-party costs directly associated with the development of a new project. Upon commencement of construction, these costs either are transferred to construction work in progress or remain in other assets, depending upon the nature of the cost. Capitalized development costs are charged to O&M expenses when it is no longer probable that these costs will be realized. NEER's construction work in progress includes construction materials, progress payments on major equipment contracts, third-party engineering costs, capitalized interest and other costs directly associated with the construction and development of various projects. Interest capitalized on construction projects amounted to approximately $135 million, $94 million and $89 million during 2019, 2018 and 2017, respectively. Interest expense allocated from NextEra Energy Capital Holdings, Inc. (NEECH) to NEER is based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy Resources' subsidiaries. Upon commencement of project operation, costs associated with construction work in progress are transferred to electric plant in service and other property. In September 2019, NEER determined it was no longer moving forward with the construction of a 220 MW wind facility due to unresolved permitting issues. NEE recorded charges of approximately $72 million ($54 million after tax), which are included in impairment charges in NEE’s consolidated statements of income for the year ended December 31, 2019, primarily related to the write-off of capitalized construction costs
Asset Retirement Obligations | Asset Retirement Obligations - NEE and FPL each account for asset retirement obligations and conditional asset retirement obligations (collectively, AROs) under accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated, with the offsetting associated asset retirement costs capitalized as part of the carrying amount of the long-lived assets. NEE's AROs relate primarily to decommissioning obligations of FPL's and NEER's nuclear units and to obligations for the dismantlement of certain of NEER's wind and solar facilities. See Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below and Note 13. For NEE's rate-regulated operations, including FPL, the asset retirement cost is subsequently allocated to a regulatory liability using a systematic and rational method over the asset's estimated useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the ARO and a decrease in the regulatory liability. Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the ARO and asset retirement cost. For NEE's non-rate regulated operations, the asset retirement cost is subsequently allocated to expense using a systematic and rational method over the asset's estimated useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense, which is included in depreciation and amortization expense in NEE's consolidated statements of income. Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the asset retirement cost, or income when asset retirement cost is depleted.
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs | Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs - For ratemaking purposes, FPL accrues for the cost of end of life retirement and disposal of its nuclear, fossil and solar plants over the expected service life of each unit based on nuclear decommissioning and fossil and solar dismantlement studies periodically filed with the FPSC. In addition, FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC. As approved by the FPSC, FPL previously suspended its annual decommissioning accrual. Any differences between expense recognized for financial reporting purposes and the amount recovered through rates are reported as a regulatory liability in accordance with regulatory accounting. See Rate Regulation, Electric Plant, Depreciation and Amortization, and Asset Retirement Obligations above and Note 13. Nuclear decommissioning studies are performed at least every five years and are submitted to the FPSC for approval. FPL filed updated nuclear decommissioning studies with the FPSC in December 2015. These studies reflect, among other things, the expiration dates of the operating licenses for FPL's nuclear units at the time of the studies. The 2015 studies provide for the dismantlement of Turkey Point Units Nos. 3 and 4 following the end of plant operation with decommissioning activities commencing in 2032 and 2033, respectively, and provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the dismantlement of St. Lucie Unit No. 2 in 2043. These studies also assume that FPL will be storing spent fuel on site pending removal to a United States (U.S.) government facility. After giving effect to the license extensions for Turkey Point Units Nos. 3 and 4, FPL's portion of the ultimate costs of decommissioning its four nuclear units, including costs associated with spent fuel storage above what is expected to be refunded by the U.S. Department of Energy (DOE) under a spent fuel settlement agreement, is estimated to be approximately $9.7 billion, or $3.3 billion expressed in 2019 dollars. FPL intends to reflect the operating license extensions for Turkey Point Units Nos. 3 and 4 in its next nuclear decommissioning studies. Restricted funds for the payment of future expenditures to decommission FPL's nuclear units are included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's and FPL's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily carried at fair value. See Note 5. Fund earnings, consisting of dividends, interest and realized gains and losses, net of taxes, are reinvested in the funds. Fund earnings, as well as any changes in unrealized gains and losses, are not recognized in income and are reflected as a corresponding offset in the related regulatory asset or liability accounts. FPL does not currently make contributions to the decommissioning funds, other than the reinvestment of fund earnings. During 2019, 2018 and 2017 fund earnings on decommissioning funds were approximately $125 million, $94 million and $114 million, respectively. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. Fossil and solar plant dismantlement studies are typically performed at least every four years and are submitted to the FPSC for approval. As part of the 2016 rate agreement, the FPSC approved an annual expense of $26 million based on FPL's 2016 fossil and solar dismantlement studies, which became effective January 1, 2017, and is recorded in depreciation and amortization expense in NEE's and FPL's consolidated statements of income. At December 31, 2019, FPL's portion of the ultimate cost to dismantle its fossil and solar units is approximately $1.2 billion, or $510 million expressed in 2019 dollars. NEER's AROs include nuclear decommissioning liabilities for Seabrook Station (Seabrook), Duane Arnold Energy Center (Duane Arnold) and Point Beach Nuclear Power Plant (Point Beach) and dismantlement liabilities for its wind and solar facilities. The liabilities are being accreted using the interest method through the date decommissioning or dismantlement activities are expected to be complete. See Note 13. At December 31, 2019 and 2018, NEER's ARO was approximately $1,097 million and $988 million, respectively, and was primarily determined using various internal and external data and applying a probability percentage to a variety of scenarios regarding the life of the plant and timing of decommissioning or dismantlement. NEER's portion of the ultimate cost of decommissioning its nuclear plants, including costs associated with spent fuel storage above what is expected to be refunded by the DOE under a spent fuel settlement agreement, is estimated to be approximately $9.5 billion, or $2.0 billion expressed in 2019 dollars. The ultimate cost to dismantle NEER's wind and solar facilities is estimated to be approximately $1.8 billion. Seabrook files a comprehensive nuclear decommissioning study with the New Hampshire Nuclear Decommissioning Financing Committee (NDFC) every four years; the most recent study was filed in 2019. Seabrook's decommissioning funding plan is also subject to annual review by the NDFC. Currently, there are no ongoing decommissioning funding requirements for Seabrook, Duane Arnold and Point Beach, however, the U.S. Nuclear Regulatory Commission (NRC), and in the case of Seabrook, the NDFC, has the authority to require additional funding in the future. NEER's portion of Seabrook's, Duane Arnold's and Point Beach's restricted funds for the payment of future expenditures to decommission these plants is included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily carried at fair value. See Note 5. Market adjustments for debt securities result in a corresponding adjustment to other comprehensive income (OCI), except for unrealized losses associated with marketable debt securities considered to be other than temporary, including any credit losses, which are recognized in other - net in NEE's consolidated statements of income. Market adjustments for equity securities are recorded in change in unrealized gains (losses) on equity securities held in NEER's nuclear decommissioning funds - net in NEE's consolidated statements of income. Fund earnings, consisting of dividends, interest and realized gains and losses are recognized in income and are reinvested in the funds. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes.
Major Maintenance Costs | Major Maintenance Costs - FPL expenses costs associated with planned fossil maintenance as incurred. FPL recognizes costs associated with planned major nuclear maintenance in accordance with regulatory treatment. FPL defers nuclear maintenance costs for each nuclear unit’s planned outage to a regulatory asset as the costs are incurred and amortizes the costs to O&M expense over the period from the end of the current outage to the end of the next planned outage. NEER uses the deferral method to account for certain planned major maintenance costs. NEER's major maintenance costs for its nuclear generation units and combustion turbines are capitalized (included in noncurrent other assets on NEE's consolidated balance sheets) and amortized to O&M expenses on a unit of production method over the period from the end of the last outage to the beginning of the next planned outage.
Cash Equivalents | Cash Equivalents - Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less.
Restricted Cash | Restricted Cash - At December 31, 2019 and 2018, NEE had approximately $508 million ($118 million for FPL) and $4,615 million ($142 million for FPL), respectively, of restricted cash, of which approximately $411 million ($54 million for FPL) and $89 million ($81 million for FPL), respectively, is included in current other assets and the remaining balance is included in noncurrent other assets on NEE's and FPL's consolidated balance sheets. Restricted cash is primarily related to debt service payments, bond proceeds held for construction at FPL and margin cash collateral requirements, and, at December 31, 2018, also related to cash restricted for the acquisition of Gulf Power Company (Gulf Power) (see Note 8 - Gulf Power Company). In addition, where offsetting positions exist, restricted cash related to margin cash collateral of $139 million is netted against derivative assets and $66 million is netted against derivative liabilities at December 31, 2019 and $184 million is netted against derivative assets at December 31, 2018. See Note 4.
Allowance for Doubtful Accounts | Allowance for Doubtful Accounts - FPL maintains an accumulated provision for uncollectible customer accounts receivable that is estimated primarily using a percentage, derived from historical revenue and write-off trends, of the previous four months of revenue. Additional amounts are included in the provision to address specific items that are not considered in the calculation described above. NEER regularly reviews collectibility of its receivables and establishes a provision for losses estimated as a percentage of accounts receivable based on the historical bad debt write-off trends for its retail electricity provider operations and, when necessary, using the specific identification method for all other receivables.
Inventory | Inventory - FPL values materials, supplies and fossil fuel inventory using a weighted-average cost method. NEER's materials, supplies and fossil fuel inventories are carried at the lower of weighted-average cost and net realizable value, unless evidence indicates that the weighted-average cost will be recovered with a normal profit upon sale in the ordinary course of business.
Energy Trading | Energy Trading - NEE provides full energy and capacity requirements services primarily to distribution utilities, which include load-following services and various ancillary services, in certain markets and engages in power and gas marketing and trading activities to optimize the value of electricity and fuel contracts, generation facilities and gas infrastructure assets, as well as to take advantage of projected favorable commodity price movements. Trading contracts that meet the definition of a derivative are accounted for at fair value and realized gains and losses from all trading contracts, including those where physical delivery is required, are recorded net for all periods presented. See Note 4.
Storm Fund and Storm Reserve | Storm Fund, Storm Reserve and Storm Cost Recovery - The storm and property insurance reserve fund (storm fund) provides coverage toward FPL's storm damage costs. Marketable securities held in the storm fund are carried at fair value. See Note 5. Fund earnings, consisting of dividends, interest and realized gains and losses, net of taxes, are reinvested in the fund. Fund earnings, as well as any changes in unrealized gains and losses, are not recognized in income and are reflected as a corresponding adjustment to the storm and property insurance reserve (storm reserve). The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. The storm fund and storm reserve are included in special use funds and noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets.
Impairment of Long-Lived Assets | Impairment of Long-Lived Assets - NEE evaluates long-lived assets for impairment when events or changes in circumstances indicate that the carrying amount may not be recoverable. An impairment loss is required to be recognized if the carrying value of the asset exceeds the undiscounted future net cash flows associated with that asset. The impairment loss to be recognized is the amount by which the carrying value of the long-lived asset exceeds the asset's fair value. In most instances, the fair value is determined by discounting estimated future cash flows using an appropriate interest rate. See Note 5 - Nonrecurring Fair Value Measurements.
Goodwill and Other Intangible Assets | NEE's, including FPL's, goodwill relates to various acquisitions which were accounted for using the purchase method of accounting. Other intangible assets are primarily included in noncurrent other assets on NEE's consolidated balance sheets. NEE's other intangible assets subject to amortization are amortized, primarily on a straight-line basis, over their estimated useful lives. Amortization expense was approximately $18 million, $19 million and $35 million for the years ended December 31, 2019, 2018 and 2017, respectively, and is expected to be approximately $18 million, $14 million, $8 million, $7 million and $4 million for 2020, 2021, 2022, 2023 and 2024, respectively. Goodwill and other intangible assets not subject to amortization are assessed for impairment at least annually by applying a fair value-based analysis. Other intangible assets subject to amortization are periodically reviewed when impairment indicators are present to assess recoverability from future operations using undiscounted future cash flows.
Pension Plan | Pension Plan - NEE records the service cost component of net periodic benefit income to O&M expense and the non-service cost component to other net periodic benefit income in NEE's consolidated statements of income. NEE allocates net periodic pension income to its subsidiaries based on the pensionable earnings of the subsidiaries' employees. Accounting guidance requires recognition of the funded status of the pension plan in the balance sheet, with changes in the funded status recognized in other comprehensive income within shareholders' equity in the year in which the changes occur. Since NEE is the plan sponsor, and its subsidiaries do not have separate rights to the plan assets or direct obligations to their employees, this accounting guidance is reflected at NEE and not allocated to the subsidiaries. The portion of previously unrecognized actuarial gains and losses and prior service costs or credits that are estimated to be allocable to FPL as net periodic (income) cost in future periods and that otherwise would be recorded in accumulated other comprehensive income (AOCI) are classified as regulatory assets and liabilities at NEE in accordance with regulatory treatment.
Stock-Based Compensation | Stock-Based Compensation - NEE accounts for stock-based payment transactions based on grant-date fair value. Compensation costs for awards with graded vesting are recognized on a straight-line basis over the requisite service period for the entire award. Forfeitures of stock-based awards are recognized as they occur. See Note 11 - Stock-Based Compensation.
Retirement of Long-Term Debt | Retirement of Long-Term Debt - For NEE's rate-regulated subsidiaries, including FPL, gains and losses that result from differences in reacquisition cost and the net book value of long-term debt which is retired are deferred as a regulatory asset or liability and amortized to interest expense ratably over the remaining life of the original issue, which is consistent with their treatment in the ratemaking process. NEE's non-rate regulated subsidiaries recognize such differences in interest expense at the time of retirement.
Income Taxes | Income Taxes - Deferred income taxes are recognized on all significant temporary differences between the financial statement and tax bases of assets and liabilities, and are presented as noncurrent on NEE's and FPL's consolidated balance sheets. In connection with the tax sharing agreement between NEE and certain of its subsidiaries, the income tax provision at each applicable subsidiary reflects the use of the "separate return method," except that tax benefits that could not be used on a separate return basis, but are used on the consolidated tax return, are recorded by the applicable subsidiary that generated the tax benefits. Any remaining consolidated income tax benefits or expenses are recorded at the corporate level. Included in other regulatory assets and other regulatory liabilities on NEE's and FPL's consolidated balance sheets is the revenue equivalent of the difference in deferred income taxes computed under accounting rules, as compared to regulatory accounting rules. The net regulatory liability totaled $4,141 million ($3,745 million for FPL) and $4,074 million ($4,042 million for FPL) at December 31, 2019 and 2018, respectively, and is being amortized in accordance with the regulatory treatment over the estimated lives of the assets or liabilities for which the deferred tax amount was initially recognized. Production tax credits (PTCs) are recognized as wind energy is generated and sold based on a per kWh rate prescribed in applicable federal and state statutes and are recorded as a reduction of current income taxes payable, unless limited by tax law in which instance they are recorded as deferred tax assets. NEER recognizes ITCs as a reduction to income tax expense when the related energy property is placed into service. FPL recognizes ITCs as a reduction to income tax expense over the depreciable life of the related energy property. At December 31, 2019 and 2018, FPL’s accumulated deferred ITCs were approximately $412 million and $326 million, respectively, and are included in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. NEE and FPL record a deferred income tax benefit created by the convertible ITCs on the difference between the financial statement and tax bases of renewable property. For NEER, this deferred income tax benefit is recorded in income tax expense in the year that the renewable property is placed in service. For FPL, this deferred income tax benefit is offset by a regulatory liability, which is amortized as a reduction of depreciation expense over the approximate lives of the related renewable property in accordance with the regulatory treatment. At December 31, 2019 and 2018, the net deferred income tax benefits associated with FPL's convertible ITCs were approximately $40 million and $42 million, respectively, and are included in noncurrent regulatory assets and noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. A valuation allowance is recorded to reduce the carrying amounts of deferred tax assets when it is more likely than not that such assets will not be realized. NEE recognizes interest income (expense) related to unrecognized tax benefits (liabilities) in interest income and interest expense, respectively, net of the amount deferred at FPL. At FPL, the offset to accrued interest receivable (payable) on income taxes is classified as a regulatory liability (regulatory asset) which will be amortized to income (expense) over a five-year period upon settlement in accordance with regulatory treatment. All tax positions taken by NEE in its income tax returns that are recognized in the financial statements must satisfy a more-likely-than-not threshold. NEE and its subsidiaries file income tax returns in the U.S. federal jurisdiction and various states, the most significant of which is Florida, and certain foreign jurisdictions. Federal tax liabilities, with the exception of certain refund claims, are effectively settled for all years prior to 2016. State and foreign tax liabilities, which have varied statutes of limitations regarding additional assessments, are generally effectively settled for years prior to 2015. At December 31, 2019, NEE had unrecognized tax benefits of approximately $79 million that, if recognized, could impact the annual effective income tax rate. The amounts of unrecognized tax benefits and related interest accruals may change within the next 12 months; however, NEE and FPL do not expect these changes to have a significant impact on NEE’s or FPL’s financial statements. See Note 6.
Sale of Differential Membership Interests | Sales of Differential Membership Interests - Certain subsidiaries of NextEra Energy Resources sold Class B membership interests in entities that have ownership interests in wind and solar facilities, with generating capacity totaling approximately 7,081 MW and 473 MW, respectively, at December 31, 2019, to third-party investors. NEE retains a controlling interest in the entities and therefore presents the Class B member interests as noncontrolling interests. Noncontrolling interests represents the portion of net assets in consolidated entities that are not owned by NEE and are reported as a component of equity in NEE’s consolidated balance sheet. The third-party investors are allocated earnings, tax attributes and cash flows in accordance with the respective limited liability company agreements. Those economics are allocated primarily to the third-party investors until they receive a targeted return (the flip date) and thereafter to NEE. NEE has the right to call the third-party interests at specified amounts if and when the flip date occurs. NEE has determined the allocation of economics between the controlling party and third-party investor should not follow the respective ownership percentages for each wind and solar project but rather the hypothetical liquidation of book value (HLBV) method based on the governing provisions in each respective limited liability company agreement. Under the HLBV method, the amounts of income and loss attributable to the noncontrolling interest reflects changes in the amount the owners would hypothetically receive at each balance sheet date under the respective liquidation provisions, assuming the net assets of these entities were liquidated at the recorded amounts, after taking into account any capital transactions, such as contributions and distributions, between the entities and the owners. At the point in time that the third-party investor, in hypothetical liquidation, would achieve its targeted return, NEE attributes the additional hypothetical proceeds to the Class B membership interests based on the call price. A loss attributable to noncontrolling interest on NEE’s consolidated statements of income represents earnings attributable to NEE. Additionally, net (income) loss attributable to noncontrolling interests in NEE's consolidated statement of income for the year ended December 31, 2018 includes a benefit to NEE of approximately $497 million ($373 million after tax) related to a reduction of differential membership interests as a result of a change in the federal corporate income tax rate effective January 1, 2018. Pursuant to previous accounting guidance, prior to 2018, the proceeds received on the sale of Class B membership interest in entities were deferred and recorded as a liability recognized in benefits associated with differential membership interests - net in NEE's consolidated statements of income as the Class B members received their portion of the economic attributes.
Redeemable Noncontrolling Interests | Redeemable Noncontrolling Interests - Certain subsidiaries of NextEra Energy Resources sold Class B membership interests in entities that have ownership interests in wind facilities to third-party investors. As specified in the respective limited liability company agreements, if, subject to certain contingencies, certain events occur, including, among others, those that would delay construction or cancel any of the underlying projects, an investor has the option to require NEER to return all or part of its investment. As these potential redemptions are outside of NEER’s control, these balances were classified as redeemable noncontrolling interests on NEE's consolidated balance sheet as of December 31, 2019 and 2018. During 2019, certain contingencies were resolved resulting in $395 million of the December 31, 2018 balance being reclassified to noncontrolling interests. The contingencies associated with the December 31, 2019 balance are expected to be resolved in 2020.
Variable Interest Entities (VIEs) | Variable Interest Entities (VIEs) - An entity is considered to be a VIE when its total equity investment at risk is not sufficient to permit the entity to finance its activities without additional subordinated financial support, or its equity investors, as a group, lack the characteristics of having a controlling financial interest. A reporting company is required to consolidate a VIE as its primary beneficiary when it has both the power to direct the activities of the VIE that most significantly impact the VIE's economic performance, and the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. NEE and FPL evaluate whether an entity is a VIE whenever reconsideration events as defined by the accounting guidance occur. See Note 9.
Leases | Leases - NEE and FPL determine if an arrangement is a lease at inception. NEE and FPL recognize a right-of-use (ROU) asset and a lease liability for operating and finance leases by recognizing and measuring leases at the commencement date based on the present value of lease payments over the lease term. For sales type leases, the book value of the leased asset is removed from the balance sheet and a net investment in sales-type lease is recognized based on fixed payments under the contract and the residual value of the asset being leased. NEE and FPL have elected not to apply the recognition requirements to short-term leases and not to separate nonlease components from associated lease components for all classes of underlying assets except for purchased power agreements. ROU assets are included primarily in noncurrent other assets, lease liabilities are included in current and noncurrent other liabilities and net investments in sales-type leases are included in current and noncurrent other assets on NEE’s and FPL's consolidated balance sheets. Operating lease expense is included in O&M expenses, amortization expense is included in depreciation and amortization expense and interest income associated with sales-type leases is included in operating revenues in NEE’s and FPL’s consolidated statements of income. See Note 14.
Acquisition-Related | Acquisition-Related - During 2019, 2018 and 2017, NEE and certain of its affiliates incurred costs related to several proposed or completed acquisitions, including transaction costs, integration costs and the payment of certain termination fees, which are included in acquisition-related expenses in NEE's consolidated statements of income. See Note 8.
Disposal of a Business/Assets | Disposal of Businesses/Assets - On February 11, 2020, a subsidiary of NextEra Energy Resources completed the sale of its ownership interest in two solar generation facilities located in Spain with a total generating capacity of 99.8 MW for net cash proceeds of approximately €117 million (approximately $128 million), subject to working capital and other adjustments. In connection with the sale, NEE anticipates recording a gain of approximately $260 million (pretax and after tax) in its consolidated statements of income during the three-months ended March 31, 2020. The carrying amounts of the major classes of assets related to the facilities that were classified as held for sale, which are included in current other assets on NEE's consolidated balance sheets, were approximately $440 million at December 31, 2019 and primarily represent property, plant and equipment. Liabilities associated with assets held for sale, which are included in current other liabilities on NEE's consolidated balance sheets, were approximately $647 million at December 31, 2019 and primarily represent long-term debt and interest rate derivatives. In June 2019, subsidiaries of NextEra Energy Resources completed the sale of ownership interests in three wind generation facilities and three solar generation facilities, including noncontrolling interests in two of the solar facilities, located in the Midwest and West regions of the U.S. with a total net ownership interest in plant capacity (net generating capacity) of 611 MW to a NEP subsidiary for cash proceeds of approximately $1.0 billion, plus working capital of $12 million. A NEER affiliate will continue to operate the facilities included in the sale. In connection with the sale, a gain of approximately $341 million ($259 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2019, which is included in gains on disposal of businesses/assets - net, and noncontrolling interests of approximately $118 million were recorded on NEE's consolidated balance sheet. In 2018, subsidiaries of NextEra Energy Resources completed the sale of its ownership interests in ten wind generation facilities and one solar generation facility located in the Midwest, South and West regions of the U.S. with a total net generating capacity of 1,388 MW to a subsidiary of NEP for net cash proceeds of approximately $1.3 billion, after transaction costs and working capital adjustments and NEP's assumption of approximately $941 million in existing noncontrolling interests related to differential membership investors. In connection with the sale and the related consolidating state income tax effects, a gain of approximately $36 million ($32 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2018 and is included in gains on disposal of businesses/assets - net. In 2017, an indirect wholly owned subsidiary of NEE completed the sale of its membership interests in its fiber-optic telecommunications business for net cash proceeds of approximately $1.1 billion, after repayment of $370 million of related long-term debt. In connection with the sale and the related consolidating state income tax effects, a gain of approximately $1.1 billion ($685 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2017 and is included in gains on disposal of businesses/assets - net.
Revenue from Contracts with Customers | Revenue from Contracts with Customers Revenue is recognized when control of the promised goods or services is transferred to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. The promised goods or services in the majority of NEE’s contracts with customers is, at FPL, for the delivery of electricity based on tariff rates approved by the FPSC and, at NEER, for the delivery of energy commodities and the availability of electric capacity and electric transmission. FPL and NEER generate substantially all of NEE’s operating revenues, which primarily include revenues from contracts with customers, as well as derivative and lease transactions at NEER. For the vast majority of contracts with customers, NEE believes that the obligation to deliver energy, capacity or transmission is satisfied over time as the customer simultaneously receives and consumes benefits as NEE performs. In 2019 and 2018, NEE’s revenue from contracts with customers was approximately $17.5 billion ($12.1 billion at FPL) and approximately $15.4 billion ($11.8 billion at FPL), respectively. NEE's and FPL's receivables are primarily associated with revenues earned from contracts with customers, as well as derivative and lease transactions at NEER, and consist of both billed and unbilled amounts, which are recorded in customer receivables and other receivables on NEE's and FPL's consolidated balance sheets. Receivables represent unconditional rights to consideration and reflect the differences in timing of revenue recognition and cash collections. For substantially all of NEE's and FPL's receivables, regardless of the type of revenue transaction from which the receivable originated, customer and counterparty credit risk is managed in the same manner and the terms and conditions of payment are similar. FPL - FPL’s revenues are derived primarily from tariff-based sales that result from providing electricity to retail customers in Florida with no defined contractual term. Electricity sales to retail customers account for approximately 90% of FPL’s operating revenues, the majority of which are to residential customers. FPL’s retail customers receive a bill monthly based on the amount of monthly kWh usage with payment due monthly. For these types of sales, FPL recognizes revenue as electricity is delivered and billed to customers, as well as an estimate for electricity delivered and not yet billed. The billed and unbilled amounts represent the value of electricity delivered to the customer. At December 31, 2019 and 2018, FPL's unbilled revenues amounted to approximately $389 million and $432 million, respectively, and are included in customer receivables on NEE’s and FPL’s consolidated balance sheets. NEER - NEER’s revenue from contracts with customers is derived primarily from the sale of energy commodities, electric capacity and electric transmission. For these types of sales, NEER recognizes revenue as energy commodities are delivered and as electric capacity and electric transmission are made available, consistent with the amounts billed to customers based on rates stipulated in the respective contracts as well as an accrual for amounts earned but not yet billed. The amounts billed and accrued represent the value of energy or transmission delivered and/or the capacity of energy or transmission available to the customer. Revenues yet to be earned under these contracts, which have maturity dates ranging from 2020 to 2053, will vary based on the volume of energy or transmission delivered and/or available. NEER’s customers typically receive bills monthly with payment due within 30 days. Certain contracts with customers contain a fixed price which primarily relate to electric capacity sales associated with independent system operator annual auctions through 2023 and certain power purchase agreements with maturity dates through 2034. At December 31, 2019, NEER expects to record approximately $945 million of revenues related to the fixed price components of such contracts over the remaining terms of the related contracts as the capacity is provided.
Derivatives | With respect to commodities related to NEE's competitive energy business, NEER employs risk management procedures to conduct its activities related to optimizing the value of its power generation and gas infrastructure assets, providing full energy and capacity requirements services primarily to distribution utilities, and engaging in power and gas marketing and trading activities to take advantage of expected future favorable price movements and changes in the expected volatility of prices in the energy markets. These risk management activities involve the use of derivative instruments executed within prescribed limits to manage the risk associated with fluctuating commodity prices. Transactions in derivative instruments are executed on recognized exchanges or via the over-the-counter (OTC) markets, depending on the most favorable credit terms and market execution factors. For NEER's power generation and gas infrastructure assets, derivative instruments are used to hedge all or a portion of the expected output of these assets. These hedges are designed to reduce the effect of adverse changes in the wholesale forward commodity markets associated with NEER's power generation and gas infrastructure assets. With regard to full energy and capacity requirements services, NEER is required to vary the quantity of energy and related services based on the load demands of the customers served. For this type of transaction, derivative instruments are used to hedge the anticipated electricity quantities required to serve these customers and reduce the effect of unfavorable changes in the forward energy markets. Additionally, NEER takes positions in energy markets based on differences between actual forward market levels and management's view of fundamental market conditions, including supply/demand imbalances, changes in traditional flows of energy, changes in short- and long-term weather patterns and anticipated regulatory and legislative outcomes. NEER uses derivative instruments to realize value from these market dislocations, subject to strict risk management limits around market, operational and credit exposure. Derivative instruments, when required to be marked to market, are recorded on NEE's and FPL's consolidated balance sheets as either an asset or liability measured at fair value. At FPL, substantially all changes in the derivatives' fair value are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the fuel and purchased power cost recovery clause (fuel clause). For NEE's non-rate regulated operations, predominantly NEER, essentially all changes in the derivatives' fair value for power purchases and sales, fuel sales and trading activities are recognized on a net basis in operating revenues; fuel purchases used in the production of electricity are recognized in fuel, purchased power and interchange expense; and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's consolidated statements of income. Settlement gains and losses are included within the line items in the consolidated statements of income to which they relate. Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the consolidated statements of income. For commodity derivatives, NEE believes that, where offsetting positions exist at the same location for the same time, the transactions are considered to have been netted and therefore physical delivery has been deemed not to have occurred for financial reporting purposes. Settlements related to derivative instruments are primarily recognized in net cash provided by operating activities in NEE's and FPL's consolidated statements of cash flows. For interest rate and foreign currency derivative instruments, essentially all changes in the derivatives' fair value, as well as the transaction gain or loss on foreign denominated debt, are recognized in interest expense and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's consolidated statements of income.
Fair Value of Financial Instruments | The fair value of assets and liabilities are determined using either unadjusted quoted prices in active markets (Level 1) or pricing inputs that are observable (Level 2) whenever that information is available and using unobservable inputs (Level 3) to estimate fair value only when relevant observable inputs are not available. NEE and FPL use several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those assets and liabilities that are measured at fair value on a recurring basis. NEE's and FPL's assessment of the significance of any particular input to the fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Non-performance risk, including the consideration of a credit valuation adjustment, is also considered in the determination of fair value for all assets and liabilities measured at fair value. Cash Equivalents and Restricted Cash Equivalents - NEE and FPL hold investments in money market funds. The fair value of these funds is estimated using a market approach based on current observable market prices. Special Use Funds and Other Investments - NEE and FPL hold primarily debt and equity securities directly, as well as indirectly through commingled funds. Substantially all directly held equity securities are valued at their quoted market prices. For directly held debt securities, multiple prices and price types are obtained from pricing vendors whenever possible, which enables cross-provider validations. A primary price source is identified based on asset type, class or issue of each security. Commingled funds, which are similar to mutual funds, are maintained by banks or investment companies and hold certain investments in accordance with a stated set of objectives. The fair value of commingled funds is primarily derived from the quoted prices in active markets of the underlying securities. Because the fund shares are offered to a limited group of investors, they are not considered to be traded in an active market. Derivative Instruments - NEE and FPL measure the fair value of commodity contracts using a combination of market and income approaches utilizing prices observed on commodities exchanges and in the OTC markets, or through the use of industry-standard valuation techniques, such as option modeling or discounted cash flows techniques, incorporating both observable and unobservable valuation inputs. The resulting measurements are the best estimate of fair value as represented by the transfer of the asset or liability through an orderly transaction in the marketplace at the measurement date. Most exchange-traded derivative assets and liabilities are valued directly using unadjusted quoted prices. For exchange-traded derivative assets and liabilities where the principal market is deemed to be inactive based on average daily volumes and open interest, the measurement is established using settlement prices from the exchanges, and therefore considered to be valued using other observable inputs. NEE, through its subsidiaries, including FPL, also enters into OTC commodity contract derivatives. The majority of these contracts are transacted at liquid trading points, and the prices for these contracts are verified using quoted prices in active markets from exchanges, brokers or pricing services for similar contracts. NEE, through NEER, also enters into full requirements contracts, which, in most cases, meet the definition of derivatives and are measured at fair value. These contracts typically have one or more inputs that are not observable and are significant to the valuation of the contract. In addition, certain exchange and non-exchange traded derivative options at NEE have one or more significant inputs that are not observable, and are valued using industry-standard option models. In all cases where NEE and FPL use significant unobservable inputs for the valuation of a commodity contract, consideration is given to the assumptions that market participants would use in valuing the asset or liability. The primary input to the valuation models for commodity contracts is the forward commodity curve for the respective instruments. Other inputs include, but are not limited to, assumptions about market liquidity, volatility, correlation and contract duration as more fully described below in Significant Unobservable Inputs Used in Recurring Fair Value Measurements. In instances where the reference markets are deemed to be inactive or do not have transactions for a similar contract, the derivative assets and liabilities may be valued using significant other observable inputs and potentially significant unobservable inputs. In such instances, the valuation for these contracts is established using techniques including extrapolation from or interpolation between actively traded contracts, or estimated basis adjustments from liquid trading points. NEE and FPL regularly evaluate and validate the inputs used to determine fair value by a number of methods, consisting of various market price verification procedures, including the use of pricing services and multiple broker quotes to support the market price of the various commodities. In all cases where there are assumptions and models used to generate inputs for valuing derivative assets and liabilities, the review and verification of the assumptions, models and changes to the models are undertaken by individuals that are independent of those responsible for estimating fair value. NEE uses interest rate contracts and foreign currency contracts to mitigate and adjust interest rate and foreign currency exchange exposure related primarily to certain outstanding and expected future debt issuances and borrowings when deemed appropriate based on market conditions or when required by financing agreements. NEE estimates the fair value of these derivatives using an income approach based on a discounted cash flows valuation technique utilizing the net amount of estimated future cash inflows and outflows related to the agreements.
Earnings Per Share | Prior to the issuance of NEE’s common stock, the stock purchase contracts, if dilutive, will be reflected in NEE’s diluted earnings per share calculations using the treasury stock method. Under this method, the number of shares of NEE common stock used in calculating diluted earnings per share is deemed to be increased by the excess, if any, of the number of shares that would be issued upon settlement of the stock purchase contracts over the number of shares that could be purchased by NEE in the market, at the average market price during the period, using the proceeds receivable upon settlement.

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