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Summary of Significant Accounting and Reporting Policies | 12 Months Ended
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Dec. 31, 2022
Accounting Policies [Abstract] |
Summary of Significant Accounting and Reporting Policies | Summary of Significant Accounting and Reporting Policies 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. On January 1, 2021, FPL and Gulf Power Company merged, with FPL as the surviving entity. However during 2021, FPL continued to be regulated as two separate ratemaking entities in the former service areas of FPL and Gulf Power. Effective January 1, 2022, FPL became regulated as one electric ratemaking entity with new unified rates and tariffs, and also became one reportable segment of NEE (see Rate Regulation – Base Rates Effective January 2022 through December 2025 below). As a result, the previous segments known as the FPL segment and Gulf Power are no longer separate reportable segments. See Note 16. FPL's principal business is a rate-regulated electric utility which supplies electric service to approximately 5.8 million customer accounts throughout most of the east and lower west coasts of Florida and eight counties throughout northwest Florida. NEER invests in independent power projects through both controlled and consolidated entities and noncontrolling owner ship 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. 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 earnings/losses of these entities is included in equity in earnings (losses) 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 c ontingent assets and liabilities. Actual results could differ from those estimates. 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 ownership interest in a portfolio of wind, solar and solar plus battery storage projects and long-term contracted natural gas pipelines. NEE owns a noncontrolling interest in NEP, accounts for 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 accounts for NextEra Energy Resources' project sales to NEP as third-party sales in its consolidated financial statements. NEER operates essentially all of the energy projects owned by NEP and provides services to NEP under various related party operations and maintenance, administrative and management services agreements. 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 Funds, Storm Reserves 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, FPL's 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 $1,035 million, $852 million and $800 million in 2022, 2021 and 2020, 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 3. 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,
| 2022 |  | 2021 |  | 2022 |  | 2021
| (millions)
Regulatory assets: |  |  |  |  |  |  |
Current: |  |  |  |  |  |  |
Early retirement of generation facilities and transmission assets(a) | $ | 145 |  |  | $ | 140 |  |  | $ | 145 |  |  | $ | 140 |
Acquisition of purchased power agreements(b) | 141 |  |  | 141 |  |  | 141 |  |  | 141 |
Deferred clause and franchise expenses | 919 |  | (c) | 698 |  |  | 919 |  | (c) | 698 |
Storm restoration costs | 911 |  | (d) | 92 |  |  | 911 |  | (d) | 92 |
Other | 49 |  |  | 54 |  |  | 39 |  |  | 40 |
Total | $ | 2,165 |  |  | $ | 1,125 |  |  | $ | 2,155 |  |  | $ | 1,111 |
Noncurrent: |  |  |  |  |  |  |
Early retirement of generation facilities and transmission assets(a) | $ | 2,026 |  |  | $ | 2,233 |  |  | $ | 2,026 |  |  | $ | 2,233 |
Acquisition of purchased power agreements(b) | 191 |  |  | 332 |  |  | 191 |  |  | 332 |
Deferred clause expenses | 1,227 |  | (c) | 17 |  |  | 1,227 |  | (c) | 17 |
Storm restoration costs | 326 |  | (d) | 150 |  |  | 326 |  | (d) | 150 |
Accrued asset removal costs(e) | 532 |  |  | 263 |  |  | 532 |  |  | 263 |
Other | 1,690 |  |  | 1,583 |  |  | 1,182 |  |  | 1,348 |
Total | $ | 5,992 |  |  | $ | 4,578 |  |  | $ | 5,484 |  |  | $ | 4,343 |
Regulatory liabilities: |  |  |  |  |  |  |
Current: |  |  |  |  |  |  |
Deferred clause revenues | $ | 339 |  |  | $ | 274 |  |  | $ | 339 |  |  | $ | 274 |
Other | 11 |  |  | 15 |  |  | 10 |  |  | 4 |
Total | $ | 350 |  |  | $ | 289 |  |  | $ | 349 |  |  | $ | 278 |
Noncurrent: |  |  |  |  |  |  |
Asset retirement obligation regulatory expense difference | $ | 3,323 |  |  | $ | 4,290 |  |  | $ | 3,323 |  |  | $ | 4,290 |
Accrued asset removal costs(e) | 658 |  |  | 782 |  |  | 623 |  |  | 752 |
Deferred taxes | 4,233 |  |  | 4,561 |  |  | 4,129 |  |  | 4,457 |
Other | 1,412 |  |  | 1,640 |  |  | 1,383 |  |  | 1,554 |
Total | $ | 9,626 |  |  | $ | 11,273 |  |  | $ | 9,458 |  |  | $ | 11,053 |
______________________ (a)The majority of these regulatory assets are being amortized over 20 years. (b)The majority of these regulatory assets are being amortized over approximately 9 years. (c)The majority of these regulatory assets are expected to be amortized over 21 months beginning April 2023. See below regarding the 2022 fuel under-recovery. (d)The majority of these regulatory assets are expected to be amortized over 12 months beginning April 2023. See Storm Funds, Storm Reserves and Storm Cost Recovery below. (e)See Electric Plant, Depreciation and Amortization below. 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, costs associated with an FPSC-approved transmission and distribution storm protection plan, certain costs associated with the acquisition and retirement 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 under-recovery or over-recovery. Any under-recovered costs or over-recovered revenues are collected from or returned to customers in subsequent periods. In January 2023, FPL filed a petition with the FPSC requesting recovery of its 2022 fuel under-recovery of approximately $2.1 billion (included in current deferred clause and franchise expenses and noncurrent deferred clause expenses above) over 21 months beginning April 2023. As a result of natural gas prices currently being lower than originally projected for 2023, FPL also requested a $1.0 billion mid-course correction to reduce the 2023 levelized fuel charges to customers that would go into effect beginning April 2023. An FPSC decision is expected in March 2023. 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. Regulatory assets and liabilities are discussed within various subsections below. Base Rates Effective January 2022 through December 2025 – In December 2021, the FPSC issued a final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2021 rate agreement). Key elements of the 2021 rate agreement, which is effective from January 2022 through at least December 2025, include, among other things, the following: •New retail base rates and charges were established for the combined utility system (including the former Gulf Power Company service area) resulting in the following increases in annualized retail base revenues: ◦$692 million beginning January 1, 2022, and ◦$560 million beginning January 1, 2023. •In addition, FPL is eligible to receive, subject to conditions specified in the 2021 rate agreement, base rate increases associated with the addition of up to 894 megawatts (MW) annually of new solar generation (through a Solar Base Rate Adjustment (SoBRA) mechanism) in each of 2024 and 2025, and may carry forward any unused MW in 2024 to 2025. FPL has agreed to an installed cost cap of $1,250 per kilowatt and will be required to demonstrate that these proposed solar facilities are cost effective. •FPL's authorized regulatory return on common equity (ROE) was 10.60%, with a range of 9.70% to 11.70%. However, in the event the average 30-year U.S. Treasury rate was 2.49% or greater over a consecutive six-month period, FPL was authorized to increase the regulatory ROE to 10.80% with a range of 9.80% to 11.80%. During August 2022, this provision was triggered and effective September 1, 2022, FPL's authorized regulatory ROE and ROE range were increased. The revised authorized regulatory ROE will have only a minimal impact to base rates. If FPL's earned regulatory ROE falls below 9.80%, FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.80%, any party with standing may seek a review of FPL's retail base rates. •Subject to certain conditions, FPL may amortize, over the term of the 2021 rate agreement, up to $1.45 billion of depreciation reserve surplus, provided that in any year of the 2021 rate agreement FPL must amortize at least enough reserve amount to maintain its minimum authorized regulatory ROE and also may not amortize any reserve amount that would result in an earned regulatory ROE in excess of its maximum authorized regulatory ROE. •FPL is authorized to expand SolarTogether™, a voluntary community solar program that gives FPL electric customers an opportunity to participate directly in the expansion of solar energy where participants pay a fixed monthly subscription charge and receive credits on their related monthly customer bill, by constructing an additional 1,788 MW of solar generation from 2022 through 2025, such that the total capacity of SolarTogether™ would be 3,278 MW. •Future storm restoration costs would be recoverable on an interim basis beginning 60 days from the filing of a cost recovery petition, but capped at an amount that produces a surcharge of no more than $4 for every 1,000 kilowatt-hour (kWh) of usage on residential bills during the first 12 months of cost recovery. Any additional costs would be eligible for recovery in subsequent years. If storm restoration costs exceed $800 million in any given calendar year, FPL may request an increase to the $4 surcharge. See Storm Funds, Storm Reserves and Storm Cost Recovery below. •If federal or state permanent corporate income tax changes become effective during the term of the 2021 rate agreement, FPL will prospectively adjust base rates after a review by the FPSC. As a result of the enactment of the Inflation Reduction Act (IRA) (see Note 5), FPL's customers are expected to save approximately $400 million over the remaining term of the 2021 rate agreement which includes a $36 million one-time refund made in January 2023. On February 8, 2023, the Florida Supreme Court heard oral argument on the appeal of the FPSC's final order regarding the 2021 rate agreement by Floridians Against Increased Rates, Inc. and, as a group, Florida Rising, Inc., Environmental Confederation of Southwest Florida, Inc. and League of United Latin American Citizens of Florida (collectively, the appellants). The appellants argue that the FPSC lacked authority to approve certain aspects of FPL's 2021 rate agreement, that the final order fails to address certain contested issues and that certain of the FPSC's findings in its final order were not adequately analyzed or supported by evidence and have requested that the final order be reversed or remanded. FPL believes that the FPSC’s decision should not be reversed or remanded by the Florida Supreme Court, because, among other things, the FPSC acted within its statutory authority in approving the 2021 rate agreement and the FPSC’s public-interest findings are supported by competent, substantial evidence in the record. A ruling by the Florida Supreme Court is pending. Base Rates Effective January 2017 through December 2021 – From January 2017 to December 2021, FPL operated under a base rate agreement (2016 rate agreement) that provided for, among other things, a regulatory ROE of 10.55%, with a range of 9.60% to 11.60% and, subject to certain conditions, the right to reduce depreciation expense up to $1.25 billion (reserve), provided that in any year of the 2016 rate agreement FPL was required to amortize enough reserve to maintain an earned regulatory ROE within the range of 9.60% to 11.60%. 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. The American Recovery and Reinvestment Act of 2009, as amended, 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, 2022 and 2021, convertible ITCs, net of amortization, were approximately $693 million ($111 million at FPL) and $755 million ($116 million at FPL). Depreciation of FPL's electric property is provided on a straight-line basis, primarily over its average remaining useful life. FPL includes in depreciation expense a provision for electric generation 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) and storm recovery amortization. For substantially all of FPL's property, depreciation studies are performed periodically and filed with the FPSC which result in updated depreciation rates. As part of the 2021 rate agreement, the FPSC approved new unified depreciation rates which became effective January 1, 2022. Reserve amortization is recorded as either an increase or decrease to accrued asset removal costs which is reflected in noncurrent regulatory assets on NEE's and FPL's consolidated balance sheets. 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 targeted regulatory ROE. In order to earn the targeted regulatory ROE in each reporting period subject to the conditions of the effective 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. See Rate Regulation – Base Rates Effective January 2022 through December 2025 above. NEER's electric plant in service and other property less salvage value, if any, are depreciated primarily using the straight-line method over their estimated useful lives. NEER reviews the estimated useful lives of its fixed assets on an ongoing basis. NEER's oil and gas production assets 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 – 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 – 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% prior to 2021 and 0.4% beginning in 2021 of a utility's plant in service balance and require more than one year to complete. FPSC rules allow construction projects below the applicable threshold as a component of rate base. 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 the related asset or sale of development rights. At December 31, 2022 and 2021, NEER's capitalized development costs totaled approximately $1,027 million and $831 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 probable that these costs will not 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 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. 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 11. For NEE's rate-regulated operations, including FPL, the asset retirement cost is allocated to a regulatory liability or regulatory asset 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 or regulatory asset. 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, or regulatory liability when asset retirement cost is depleted. For NEE's non-rate regulated operations, the asset retirement cost is 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 – For ratemaking purposes, FPL accrues for the cost of end of life retirement and disposal of its nuclear and other generation plants over the expected service life of each unit based on nuclear decommissioning and other generation 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 asset or liability in accordance with regulatory accounting. See Rate Regulation, Electric Plant, Depreciation and Amortization, and Asset Retirement Obligations above and Note 11. Nuclear decommissioning studies are performed at least every five years and are filed with the FPSC for approval. FPL filed updated nuclear decommissioning studies with the FPSC in December 2020. 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 2020 studies provide for the dismantlement of Turkey Point Units Nos. 3 and 4 following the end of plant operation with decommissioning activities commencing in 2052 and 2053, respectively, however, in 2022, the U.S. Nuclear Regulatory Commission (NRC) amended Turkey Point Units Nos. 3 and 4 license renewals by removing the 20 additional years of operation reflected in the studies. FPL filed a site-specific environmental impact statement with the NRC related to the previously approved 20-year renewal application for both Turkey Point operating licenses. Approval of the additional 20 years of operations is pending. The studies filed in 2020 also 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. 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 $9.6 billion, or $2.5 billion expressed in 2022 dollars. The ultimate costs of decommissioning reflect the applications submitted to the NRC for the extension of Turkey Point Units Nos. 3 and 4 and St. Lucie Units Nos. 1 and 2 licenses for an additional 20 years. 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 4. 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 and estimated credit losses on debt securities, 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 2022, 2021 and 2020 fund earnings on decommissioning funds were approximately $58 million, $173 million and $132 million, respectively. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. Other generation plant dismantlement studies are performed periodically and are submitted to the FPSC for approval. Previously approved studies were effective from January 1, 2017 through December 2021 and resulted in an annual expense of $26 million which is recorded in depreciation and amortization expense in NEE's and FPL's consolidated statements of income. As part of the 2021 rate agreement, the FPSC approved a new annual expense of $48 million based on FPL's updated dismantlement studies which became effective January 1, 2022. At December 31, 2022, FPL's portion of the ultimate cost to dismantle its other generation units is approximately $2.4 billion, or $1.2 billion expressed in 2022 dollars. NEER's AROs primarily 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 11. At December 31, 2022 and 2021, NEER's ARO was approximately $1.2 billion and $1.1 billion, 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 2022 dollars. The ultimate cost to dismantle NEER's wind and solar facilities is estimated to be approximately $2.5 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 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 4. Market adjustments for debt securities result in a corresponding adjustment to other comprehensive income (OCI), except for estimated credit losses and unrealized losses on debt securities intended or required to be sold prior to recovery of the amortized cost basis, 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 – FPL expenses costs associated with planned maintenance for its non-nuclear electric generation plants 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. FPL amortizes the costs to O&M expense using the straight-line method over the period from the end of the current outage to the next planned outage where the respective work scope is performed. 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 expense using the straight-line method over the period from the end of the current outage to the next planned outage where the respective work scope is performed. Cash Equivalents – Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less. Restricted Cash – At December 31, 2022 and 2021, NEE had approximately $1,840 million ($33 million for FPL) and $677 million ($53 million for FPL), respectively, of restricted cash, which is included in current other assets on NEE's and FPL's consolidated balance sheets. Restricted cash is primarily related to debt service payments and margin cash collateral requirements at NEER and bond proceeds held for construction at FPL. In addition, where offsetting positions exist, restricted cash related to margin cash collateral of $7 million is netted against derivative assets and $1,541 million is netted against derivative liabilities at December 31, 2022 and $121 million is netted against derivative assets and $172 million is netted against derivative liabilities at December 31, 2021. See Note 3. Measurement of Credit Losses on Financial Instruments – Effective January 1, 2020, NEE and FPL adopted an accounting standards update that provides for a new methodology, the current expected credit loss (CECL) model, to account for credit losses for certain financial assets measured at amortized cost. On January 1, 2020, NEE recorded a reduction to retained earnings of approximately $11 million representing the cumulative effect of adopting the new standards update, which primarily related to the impact of applying the CECL model to NEER's receivables. The impact of adopting the new standards update was not material to FPL. Allowance for Doubtful Accounts and Bad Debt – FPL maintains an accumulated provision for uncollectible customer accounts receivable that is estimated using a percentage, derived from historical revenue and write-off trends, of the previous four months of revenue, and includes estimates of credit and other losses based on both current events and forecasts. 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, as well as includes estimates for credit and other losses based on both current events and forecasts. When necessary, NEER uses the specific identification method for all other receivables. Credit Losses – NEE's credit department monitors current and forward credit exposure to counterparties and their affiliates. Prospective and existing customers are reviewed for creditworthiness based on established standards and credit quality indicators. Credit quality indicators and standards that are closely monitored include credit ratings, certain financial ratios and delinquency trends which are based off the latest available information. Customers not meeting minimum standards provide various credit enhancements or secured payment terms, such as letters of credit, the posting of margin cash collateral or use of master netting arrangements. For the years ended December 31, 2022, 2021 and 2020, NEE recorded approximately $113 million, $146 million and $94 million of bad debt expense, including credit losses, respectively, which are included in O&M expenses in NEE’s consolidated statements of income. The amounts recorded in 2021 primarily relate to credit losses at NEER driven by the operational and energy market impacts of severe prolonged winter weather in Texas in February 2021 (February 2021 weather event). The estimate for credit losses related to the impacts of the February 2021 weather event was developed based on NEE’s assessment of the ultimate collectability of these receivables. At December 31, 2021, approximately $127 million of allowances were included in noncurrent other assets on NEE's consolidated balance sheet related to the February 2021 weather event. During 2022, the net receivable was settled. Inventory – FPL values materials, supplies and fuel inventory using a weighted-average cost method. NEER's materials, supplies and fuel inventories, which include emissions allowances and renewable energy credits, 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 – 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 fuel 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 3. Storm Funds, Storm Reserves and Storm Cost Recovery – The storm funds provide coverage toward FPL's storm damage costs. Marketable securities held in the storm funds are carried at fair value. See Note 4. 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 adjustment to the storm reserve. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. The storm funds are included in special use funds and the storm reserves in noncurrent regulatory liabilities, or in the case of a deficit, in regulatory assets on NEE's and FPL's consolidated balance sheets. During 2022, FPL’s service area was impacted by Hurricane Ian in September and Hurricane Nicole in November which resulted in total recoverable storm restoration costs of approximately $1.3 billion. Prior to Hurricane Ian, FPL’s storm reserve had a balance of approximately $220 million. At December 31, 2022, the recoverable storm restoration costs associated with Hurricane Ian and Hurricane Nicole exceeded the balance of the storm reserve by approximately $1.1 billion. This deficit has been recorded by FPL as current and noncurrent regulatory assets on NEE’s and FPL’s December 31, 2022 consolidated balance sheets. In January 2023, FPL filed a petition with the FPSC requesting the recovery of eligible storm restoration costs over the reserve amount, plus approximately $220 million to replenish the reserve, through an interim surcharge that would apply for a 12-month period beginning April 1, 2023. While a 12-month recovery period would reduce the potential bill impacts in the event of 2023 storm activity, the FPSC may approve a longer recovery period. The amount collected will be subject to refund based on an FPSC prudence review. In addition, FPL also provided information that incorporates the remaining unrecovered pre-2022 northwest Florida service area storm restoration costs (see below for a discussion of such costs), estimated to be approximately $136 million at April 1, 2023, into the interim surcharge discussed above. The unpaid portion of the storm restoration costs at December 31, 2022, of approximately $618 million, including estimated capital costs, is included in other current liabilities on NEE’s and FPL’s consolidated balance sheet. During 2021 and 2020, FPL’s service area was impacted by hurricanes and tropical storms, which resulted in the recording of incremental storm restoration costs. FPL determined that it would not seek recovery of certain of such costs associated with the 2016 rate agreement through a storm surcharge from customers and instead recorded approximately $28 million and $183 million in 2021 and 2020, respectively, as storm restoration costs in NEE's and FPL’s consolidated statements of income (included in O&M expenses). FPL used available reserve amortization to offset all such storm restoration costs that were expensed. Restoration costs associated with multiple storms since 2018 that impacted FPL's customers in the former Gulf Power Company service area are being collected from FPL's northwest Florida customers through a storm damage surcharge through late 2024 and are recorded as regulatory assets. As of December 31, 2022, the balance was $155 million, of which $101 million and $54 million are included in current regulatory assets and noncurrent regulatory assets, respectively, on NEE's and FPL's consolidated balance sheets. As of December 31, 2021, the balance was $242 million, of which $92 million and $150 million are included in current regulatory assets and noncurrent regulatory assets, respectively, on NEE's and FPL's consolidated balance sheets. 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. 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. Impairment of Equity Method Investments – NEE evaluates its equity method investments for impairment when events or changes in circumstances indicate that the fair value of the investment is less than the carrying value and the investment may be other-than-temporarily impaired. An impairment loss is required to be recognized if the impairment is deemed to be other than temporary. Investments that are other-than-temporarily impaired are written down to their estimated fair value and cannot subsequently be written back up for increases in estimated fair value. Impairment losses are recorded in equity in earnings (losses) of equity method investees in NEE’s consolidated statements of income. See Note 4 – Nonrecurring Fair Value Measurements. Goodwill and Other Intangible Assets – NEE's goodwill and other intangible assets are as follows:
| Weighted- Average Useful Lives |  | December 31,
|  | 2022 |  | 2021
| (years) |  | (millions)
Goodwill (by reporting unit): |  |  |  |  |
FPL segment, primarily rate-regulated utilities (see Note 6 – Merger of FPL and Gulf Power Company) |  |  | $ | 2,989 |  |  | $ | 2,989 |
NEER segment: |  |  |  |  |
Rate-regulated assets, primarily transmission (see Note 6 – GridLiance) |  |  | 1,218 |  |  | 1,206 |
Gas infrastructure |  |  | 487 |  |  | 487 |
Customer supply and trading |  |  | 95 |  |  | 95 |
Clean energy assets |  |  | 54 |  |  | 56 |
Corporate and Other |  |  | 11 |  |  | 11 |
Total goodwill |  |  | $ | 4,854 |  |  | $ | 4,844 |
Other intangible assets not subject to amortization, primarily land easements |  |  | $ | 136 |  |  | $ | 136 |
Other intangible assets subject to amortization: |  |  |  |  |
Purchased power agreements | 16 |  | $ | 549 |  |  | $ | 507 |
Other, primarily transportation contracts and customer lists | 24 |  | 173 |  |  | 187 |
Total |  |  | 722 |  |  | 694 |
Accumulated amortization |  |  | (99) |  |  | (88) |
Total other intangible assets subject to amortization – net |  |  | $ | 623 |  |  | $ | 606 |
NEE's, including FPL's, goodwill relates to various acquisitions which were accounted for using the acquisition 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, $25 million and $27 million for the years ended December 31, 2022, 2021 and 2020, respectively, and is expected to be approximately $20 million, $22 million, $20 million, $22 million and $20 million for 2023, 2024, 2025, 2026 and 2027, 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 – 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 – 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 14 – Stock-Based Compensation. 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. Reference Rate Reform – In March 2020, the Financial Accounting Standards Board issued an accounting standards update which provides certain options to apply accounting guidance on contract modifications and hedge accounting as companies transition from the London Inter-Bank Offered Rate (LIBOR) and other interbank offered rates to alternative reference rates. NEE’s and FPL’s contracts that reference LIBOR or other interbank offered rates mainly relate to debt and derivative instruments. The standards update was effective upon issuance but can be applied prospectively through December 31, 2024. During the fourth quarter of 2021, NEE began utilizing options provided by the standards update with regard to modifications to debt and debt-related hedging instruments. NEE will continue to evaluate reference rate modifications to debt and derivative instruments through December 31, 2024 and continue to apply the standards update if eligible. Although the full impact is unknown, to date there has not been a material impact to NEE or FPL. 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 $3,504 million ($3,449 million for FPL) and $3,780 million ($3,723 million for FPL) at December 31, 2022 and 2021, 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 and solar 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, 2022 and 2021, FPL’s accumulated deferred ITCs were approximately $1,031 million and $1,054 million, respectively, and are included in 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 2017. State and foreign tax liabilities, which have varied statutes of limitations regarding additional assessments, are generally effectively settled for years prior to 2017. At December 31, 2022, NEE had unrecognized tax benefits of approximately $119 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 5. Sales of Differential Membership Interests – Certain subsidiaries of NextEra Energy Resources sold Class B membership interests in entities that have ownership interests in wind generation, solar generation and battery storage facilities, with generating/storage capacity in operation or under construction totaling approximately 12,413 MW, 2,360 MW and 714 MW, respectively, at December 31, 2022, 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 generation, solar generation and battery storage 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 interests on NEE’s consolidated statements of income represents earnings attributable to NEE. Redeemable Noncontrolling Interests – Certain subsidiaries of NextEra Energy Resources sold Class B membership interests in entities that have ownership interests in wind generation, as well as solar and solar plus battery storage 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 completion 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 were outside of NEER’s control, these balances were classified as redeemable noncontrolling interests on NEE's consolidated balance sheets as of December 31, 2022 and 2021. During 2022, the contingencies associated with the December 31, 2021 balance were resolved and reclassified to noncontrolling interests. The contingencies associated with the December 31, 2022 balance are expected to be resolved in 2023. 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 – 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 includ ed 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 fuel, purchased power and interchange or O&M expenses, interest and amortization expenses associated with finance leases are included in interest expense and depreciation and amortization expense, respectively, and rental income associated with operating leases and interest income associated with sales-type leases are included in operating revenues in NEE’s and FPL’s consolidated statements of income. See Note 10. Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests – In December 2022, subsidiaries of NextEra Energy Resources sold (i) a 49% controlling ownership interest in three wind generation facilities and one solar plus battery facility located in geographically diverse locations throughout the U.S. with a total generating capacity of 1,437 MW and 65 MW of battery storage capacity, two of which facilities are currently under construction with expected in service dates in 2023, and (ii) their 100% ownership interest in three wind generation facilities located in the Midwest region of the U.S. with a total generating capacity of 347 MW to a NEP subsidiary for cash proceeds of approximately $805 million, plus working capital and other adjustments of $8 million (subject to post-closing adjustments). NEER will continue to consolidate the projects currently under construction for accounting purposes. A NextEra Energy Resources affiliate will continue to operate the facilities included in the sale. In connection with the sale, a gain of approximately $301 million ($230 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2022 and is included in the gains on disposal of businesses/assets – net. In connection with the facilities currently under construction, approximately $251 million of cash received was recorded as contract liabilities, which is included in current other liabilities on NEE's consolidated balance sheet at December 31, 2022. The contract liabilities relate to sale proceeds from NEP of approximately $150 million and differential membership interests of approximately $101 million. The contract liabilities associated with the sale proceeds and the differential membership interests are subject to the two facilities under construction achieving commercial operations by specified dates in 2023. The contract liabilities will be reversed and the sale recognized for accounting purposes if the contingencies are resolved in 2023. Otherwise, NextEra Energy Resources may be required to return proceeds related to differential membership interests and/or repurchase the facilities for up to $251 million. In addition, NextEra Energy Resources is responsible to pay for all construction costs related to the portfolio. At December 31, 2022, approximately $810 million is included in accounts payable on NEE's consolidated balance sheet and represents amounts owed by NextEra Energy Resources to NEP to reimburse NEP for construction costs. In September 2022, subsidiaries of NextEra Energy Resources completed the sale to a NEP subsidiary of a 67% controlling ownership interest in a battery storage facility in California with storage capacity of 230 MW, for cash proceeds of approximately $191 million, plus working capital and other adjustments of $2 million. A NextEra Energy Resources affiliate will continue to operate the facility included in the sale. In connection with the sale, a gain of approximately $87 million ($66 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2022 and is included in gains on disposal of businesses/assets – net. In December 2021, subsidiaries of NextEra Energy Resources sold their 100% ownership interest, comprised of a 50% controlling ownership interest to a NEP subsidiary and a 50% noncontrolling ownership interest to a third party, in a portfolio of seven wind generation facilities and six solar generation facilities in geographically diverse locations throughout the U.S. representing a total generating capacity of 2,520 MW and 115 MW of battery storage capacity, three of which facilities were under construction. Total cash proceeds for these two separate transactions totaled approximately $1.7 billion. NEER continued to consolidate the three projects under construction for accounting purposes through the first quarter of 2022. A NextEra Energy Resources affiliate will continue to operate the facilities included in the sales. In connection with the sales, a loss of approximately $53 million ($33 million after tax) was recorded in NEE’s consolidated statements of income for the year ended December 31, 2021 and is included in gains on disposal of businesses/assets – net. In connection with the three facilities that were under construction, approximately $668 million of cash received was recorded as contract liabilities, which is included in current other liabilities on NEE’s consolidated balance sheet at December 31, 2021. The contract liabilities related to sale proceeds from NEP and the third party of approximately $349 million and differential membership interests of approximately $319 million, of which $117 million was contingent on the enactment of a solar PTC by a specified date in 2022. In 2022, the three facilities achieved commercial operations and approximately $551 million of contract liabilities were reversed and the sale of those facilities was recognized for accounting purposes. In addition, the IRA was enacted establishing a solar PTC (see Note 5) which resolved the outstanding contingencies and $117 million of contract liabilities were reversed and a gain was recorded in NEE's consolidated statements of income for the year ended December 31, 2022 which is included in gains on disposal of businesses/assets – net. In addition, NextEra Energy Resources was responsible to pay for all construction costs related to the portfolio. At December 31, 2021, approximately $970 million was included in accounts payable on NEE's consolidated balance sheet and represented amounts owed by NextEra Energy Resources to NEP to reimburse NEP for construction costs. In 2021, subsidiaries of NextEra Energy Resources completed the sale to a NEP subsidiary of their 100% ownership interests in three wind generation facilities and one solar generation facility located in the West and Midwest regions of the U.S. with a total generating capacity of 467 MW and 33.3% of the noncontrolling ownership interests in four solar generation facilities and multiple distributed generation solar facilities located in geographically diverse locations throughout the U.S. representing a total net ownership interest in plant capacity (net generating capacity) of 122 MW for cash proceeds of approximately $563 million, plus working capital and other adjustments of $22 million. A NextEra Energy Resources affiliate will continue to operate the facilities included in the sale. In connection with the sale, a gain of approximately $94 million ($69 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2021, which is included in gains on disposal of businesses/assets, and noncontrolling interests of approximately $125 million and additional paid-in capital of approximately $60 million ($43 million after tax) were recorded on NEE's consolidated balance sheet at December 31, 2021. In 2020, a subsidiary of NextEra Energy Resources sold a 90% noncontrolling ownership interest, comprised of a 50% ownership interest to a third party and a 40% ownership interest to a NEP subsidiary, in a portfolio of three wind generation facilities and four solar generation facilities in geographically diverse locations throughout the U.S. representing a total net generating capacity of 900 MW. In addition, a subsidiary of NextEra Energy Resources also sold its 100% ownership interest in a 100 MW solar generation facility and a 30 MW battery storage facility (solar-plus-storage facility) that was under construction in Arizona to a NEP subsidiary. Total cash proceeds for these two separate transactions totaled approximately $656 million. NEER continued to consolidate the projects until the sale was recognized for accounting purposes, see Note 9 – NEER. A NextEra Energy Resources affiliate will continue to operate the facilities included in the sale. I n connection with the 90% sale, noncontrolling interests of approximately $689 million and a reduction to additional paid-in capital of approximately $188 million ($165 million after tax) were recorded on NEE's consolidated balance sheet. In connection with the solar-plus-storage facility transaction, approximately $155 million of cash received was recorded as a contract liability, and upon the solar-plus-storage facility achieving commercial operations in 2021, the contract liability was reversed and the sale was recognized for accounting purposes. In 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, which resulted in net cash proceeds of approximately €111 million (approximately $121 million). In connection with the sale, a gain of approximately $270 million (pretax and after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2020 and is included in gains on disposal of businesses/assets – net.

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