NEXTERA ENERGY INC (NEE) FY 2021 MD&A

Item 7.  Management’s Discussion and Analysis of Financial Condition and Results of Operations

OVERVIEW

NEE’s operating performance is driven primarily by the operations of its two principal businesses, FPL, which serves more than 5.7 million customer accounts in Florida and is one of the largest electric utilities in the U.S., and NEER, which together with affiliated entities is the world's largest generator of renewable energy from the wind and sun based on 2021 MWh produced on a net generation basis. The table below presents net income (loss) attributable to NEE and earnings (loss) per share attributable to NEE, assuming dilution, by reportable segment, the FPL segment and NEER, as well as an operating segment of NEE, Gulf Power, which was acquired by NEE in January 2019 and merged into FPL on January 1, 2021 (see Note 6 – Merger of FPL and Gulf Power Company). Corporate and Other is primarily comprised of the operating results of other business activities, as well as other income and expense items, including interest expense, and eliminating entries, and may include the net effect of rounding. The following discussion should be read in conjunction with the Notes to Consolidated Financial Statements contained herein and all comparisons are with the corresponding items in the prior year.

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(a)    NEER’s results reflect an allocation of interest expense from NEECH based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy Resources' subsidiaries.

For the five years ended December 31, 2021, NEE delivered a total shareholder return of approximately 251.8%, above the S&P 500’s 133.4% return, the S&P 500 Utilities' 74.4% return and the Dow Jones U.S. Electricity's 74.1% return. The historical stock performance of NEE's common stock shown in the performance graph below is not necessarily indicative of future stock price performance.

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Adjusted Earnings

NEE prepares its financial statements under GAAP. However, management uses earnings adjusted for certain items (adjusted earnings), a non-GAAP financial measure, internally for financial planning, analysis of performance, reporting of results to the Board of Directors and as an input in determining performance-based compensation under NEE’s employee incentive compensation plans. NEE also uses adjusted earnings when communicating its financial results and earnings outlook to analysts and investors. NEE’s management believes that adjusted earnings provide a more meaningful representation of NEE's fundamental earnings power. Although these amounts are properly reflected in the determination of net income under GAAP, management believes that the amount and/or nature of such items make period to period comparisons of operations difficult and potentially confusing. Adjusted earnings do not represent a substitute for net income, as prepared under GAAP.

The following table provides details of the after-tax adjustments to net income considered in computing NEE's adjusted earnings discussed above.

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(a)For 2021, 2020 and 2019, approximately $1,735 million, $438 million and $65 million of losses, respectively, are included in NEER's net income; the balance is included in Corporate and Other. The change in non-qualifying hedge activity is primarily attributable to changes in forward power and natural gas prices, interest rates and foreign currency exchange rates, as well as the reversal of previously recognized unrealized mark-to-market gains or losses as the underlying transactions were realized.

(b)See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests for a discussion of the sale of two solar generation facilities in Spain (Spain projects).

(c)For 2019, approximately $44 million, $20 million and $6 million of costs are included in Corporate and Other's, Gulf Power's and NEER's net income, respectively.

(d)See Note 4 – Nonrecurring Fair Value Measurements for a discussion of the impairment charge in 2020 related to the investment in Mountain Valley Pipeline, LLC (Mountain Valley Pipeline).

NEE segregates into two categories unrealized mark-to-market gains and losses and timing impacts related to derivative transactions. The first category, referred to as non-qualifying hedges, represents certain energy derivative, interest rate derivative and foreign currency transactions entered into as economic hedges, which do not meet the requirements for hedge accounting, or for which hedge accounting treatment is not elected or has been discontinued. Changes in the fair value of those transactions are marked to market and reported in the consolidated statements of income, resulting in earnings volatility because the economic offset to certain of the positions are generally not marked to market. As a consequence, NEE's net income reflects only the movement in one part of economically-linked transactions. For example, a gain (loss) in the non-qualifying hedge category for certain energy derivatives is offset by decreases (increases) in the fair value of related physical asset positions in the portfolio or contracts, which are not marked to market under GAAP. For this reason, NEE's management views results expressed excluding the impact of the non-qualifying hedges as a meaningful measure of current period performance. The second category, referred to as trading activities, which is included in adjusted earnings, represents the net unrealized effect of actively traded positions entered into to take advantage of expected market price movements and all other commodity hedging activities. At FPL, substantially all changes in the fair value of energy derivative transactions 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 clause. See Note 3.

2021 Summary

Net income attributable to NEE for 2021 was higher than 2020 by $654 million, or $0.33 per share, assuming dilution, due to higher results at the FPL segment, Corporate and Other, NEER and Gulf Power.

FPL's net income increased by $316 million in 2021 primarily reflecting higher results at the FPL segment and at Gulf Power. The FPL segment's increase in net income for 2021 was primarily driven by continued investments in plant in service and other property. Gulf Power's increase in net income in 2021 was primarily driven by reductions in O&M expenses.

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NEER's results increased in 2021 primarily driven by the absence of an impairment charge related to its investment in Mountain Valley Pipeline occurring in 2020 and higher earnings on new investments, partly offset by unfavorable non-qualifying hedge activity compared to 2020 and the absence of the 2020 gain on the sale of the Spain projects. In 2021, NEER added approximately 2,008 MW of new wind generating capacity and 728 MW of solar generating capacity, repowered 435 MW of wind generating capacity and increased its backlog of contracted renewable development projects.

Corporate and Other's results in 2021 increased primarily due to favorable non-qualifying hedge activity.

NEE and its subsidiaries require funds to support and grow their businesses. These funds are primarily provided by cash flows from operations, borrowings or issuances of short- and long-term debt, proceeds from differential membership investors, sales of assets to NEP or third parties and, from time to time, issuances of equity securities. See Liquidity and Capital Resources – Liquidity.

RESULTS OF OPERATIONS

Net income attributable to NEE for 2021 was $3.57 billion compared to $2.92 billion in 2020. In 2021, net income attributable to NEE increased primarily due to higher results at the FPL segment, Corporate and Other, NEER and Gulf Power. The comparison of the results of operations for the years ended December 31, 2020 and 2019 are included in Management's Discussion in NEE's and FPL's Annual Report on Form 10-K for the year ended December 31, 2020.

In February 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. In December 2020, a subsidiary of NextEra Energy Resources sold a 90% noncontrolling ownership interest in a portfolio of three wind generation facilities and four solar generation facilities representing a total net generating capacity of 900 MW. Additionally in December 2020, a subsidiary of NextEra Energy Resources sold its 100% ownership interest in a 100 MW solar generation facility and a 30 MW battery storage facility under construction, which achieved commercial operations in June 2021, to a NEP subsidiary. In October 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 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 representing a total net generating capacity of 122 MW. In December 2021, subsidiaries of NextEra Energy Resources sold their 100% ownership interest in a portfolio of seven wind generation facilities and six solar generation facilities representing a total generating capacity of 2,520 MW and 115 MW of battery storage capacity, three of which are currently under construction with expected in-service dates in the first half of 2022. See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

In March 2021, a wholly owned subsidiary of NEET acquired GridLiance Holdco, LP and GridLiance GP, LLC (GridLiance), which owns and operates three FERC-regulated transmission utilities across six states, five in the Midwest and Nevada. See Note 6 – GridLiance.

NEE's effective income tax rates for the years ended December 31, 2021 and 2020 were approximately 11% and 2%, respectively. The rates for both years reflect the impact of PTCs and ITCs and, in 2020, also reflect the impact of lower pretax income and the gain on sale of the Spain solar projects which was not taxable for federal nor state income tax purposes. See Note 5.

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. The FPL segment and Gulf Power continued to be separate operating segments of NEE, as well as FPL, through 2021. See Note 6 – Merger of FPL and Gulf Power Company. Effective January 1, 2022, FPL became regulated as one ratemaking entity with new unified rates and tariffs, and also became one operating segment of NEE. See Item 1. Business – FPL – FPL Regulation – FPL Electric Rate Regulation – Base Rates – Base Rates Effective January 2022 through December 2025.

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FPL: Results of Operations

The table below presents net income for FPL by reportable segment, the FPL segment and Gulf Power. Prior year FPL amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company discussed above. In the following discussions, all comparisons are with the corresponding items in the prior year.

FPL Segment: Results of Operations

The FPL segment obtains its operating revenues primarily from the sale of electricity to retail customers at rates established by the FPSC through base rates and cost recovery clause mechanisms. The FPL segment’s net income for 2021 and 2020 was $2,935 million and $2,650 million, respectively, representing an increase of $285 million. The increase was primarily driven by higher earnings from investments in plant in service and other property. Such investments grew the FPL segment's average retail rate base by approximately $3.3 billion in 2021 and reflect, among other things, solar generation additions and ongoing transmission and distribution additions.

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 through a storm surcharge from customers and instead recorded such costs as storm restoration costs in NEE's and FPL’s consolidated statements of income. The FPL segment used available reserve amortization to offset all such storm restoration costs that were expensed. See Note 1 – Storm Funds, Storm Reserves and Storm Cost Recovery.

The use of reserve amortization was permitted by the 2016 rate agreement. See Item 1. Business – FPL – FPL Regulation – FPL Electric Rate Regulation – Base Rates – Base Rates Effective January 2017 through December 2021 for additional information on the 2016 rate agreement. In order to earn a targeted regulatory ROE, subject to limitations associated with the 2016 rate agreement, reserve amortization was 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 must be adjusted, in part, by reserve amortization to earn the targeted regulatory ROE. In certain periods, reserve amortization is reversed so as not to exceed the targeted regulatory ROE. The drivers of the FPL segment's net income not reflected in the reserve amortization calculation typically include wholesale and transmission service revenues and expenses, cost recovery clause revenues and expenses, AFUDC – equity and revenue and costs not recoverable from retail customers. In 2021 and 2020, the FPL segment recorded reserve amortization of approximately $429 million and the reversal of reserve amortization of $1 million, respectively. The FPL segment's regulatory ROE for both 2021 and 2020 was approximately 11.60%.

In December 2021, the FPSC issued a final order approving the 2021 rate agreement which became effective in January 2022 and will remain in effect until at least December 2025, establishes FPL's allowed regulatory ROE at 10.60%, with a range of 9.70% to 11.70%, and allows for retail rate base increases in 2022 and 2023. In December 2021, Floridians Against Increased Rates, Inc. and, as a group in January 2022, Florida Rising, Inc., Environmental Confederation of Southwest Florida, Inc., and League of United Latin American Citizens of Florida filed notices of appeal challenging the FPSC's final order approving the 2021 rate agreement, which notices of appeal are pending before the Florida Supreme Court. See Item 1. Business – FPL – FPL Regulation – FPL Electric Rate Regulation – Base Rates – Base Rates Effective January 2022 through December 2025 for additional information on the 2021 rate agreement.

During 2021, operating revenues increased $938 million primarily related to higher fuel cost recovery revenues as discussed in cost recovery clauses below.

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Retail Base

The FPL segment’s retail base revenues for 2021 and 2020 reflect the 2016 rate agreement. In December 2016, the FPSC issued a final order approving the 2016 rate agreement which became effective in January 2017 and remained in effect until December 2021. The 2016 rate agreement established the FPL segment's allowed regulatory ROE at 10.55%, with a range of 9.60% to 11.60%, and allowed for retail rate base increases in 2017, 2018, and upon commencement of commercial operations at the Okeechobee Clean Energy Center and certain solar projects. See Item 1. Business – FPL – FPL Regulation – FPL Electric Rate Regulation – Base Rates – Base Rates Effective January 2017 through December 2021 for additional information on the 2016 rate agreement.

Retail base revenues decreased $9 million during the year ended December 31, 2021 and were impacted by a decrease of 2.6% in the average usage per retail customer, primarily related to unfavorable weather when compared to the prior year, partly offset by an increase of 1.5% in the average number of customer accounts. See Note 1 – Rate Regulation.

Cost Recovery Clauses

Revenues from fuel and other cost recovery clauses and pass-through costs, such as franchise fees, revenue taxes and storm-related surcharges, are largely a pass-through of costs. Such revenues also include a return on investment allowed to be recovered through the cost recovery clauses on certain assets, primarily related to certain solar, environmental projects, storm protection plan investments and the unamortized balance of the regulatory asset associated with the FPL segment's acquisition of certain generation facilities. See Item 1. Business – FPL – FPL Regulation – FPL Electric Rate Regulation – Cost Recovery Clauses. Underrecovery or overrecovery of cost recovery clause and other pass-through costs (deferred clause and franchise expenses and revenues) can significantly affect NEE's and FPL's operating cash flows. The 2021 net underrecovery impacting the FPL segment's operating cash flows was approximately $516 million, primarily related to the fuel cost recovery clause.

Fuel cost recovery revenues increased approximately $775 million in 2021 primarily as a result of higher fuel and energy prices. In 2021 and 2020, cost recovery clauses contributed approximately $124 million and $111 million, respectively, to the FPL segment’s net income. FPL's fuel cost recovery clause revenues and expenses are expected to increase in 2022 as a result of the collection of underrecovered 2021 fuel costs and higher projected natural gas prices in 2022.

Other Items Impacting the FPL Segment's Consolidated Statements of Income

Fuel, Purchase Power and Interchange Expense

Fuel, purchased power and interchange expense increased $807 million in 2021 primarily related to higher fuel and energy prices.

Depreciation and Amortization Expense

The major components of the FPL segment’s depreciation and amortization expense are as follows:

Depreciation expense decreased $278 million during 2021 primarily reflecting the recording of reserve amortization in 2021 compared to the reversal of reserve amortization in 2020, partly offset by increased depreciation related to higher plant in service balances. Reserve amortization, or reversal of such amortization, reflects adjustments to accrued asset removal costs provided under the 2016 rate agreement in order to achieve the targeted regulatory ROE. Reserve amortization is recorded as either an increase or decrease to accrued asset removal costs which is reflected in noncurrent regulatory assets at December 31, 2021 and in noncurrent regulatory liabilities at December 31, 2020 on NEE's and FPL's consolidated balance sheets. See Note 1 –Rate Regulation – Base Rates Effective January 2022 through December 2025 – and Electric Plant, Depreciation and Amortization – for discussion of reserve amortization, including certain limitations on reserve amortization in 2022, and new unified depreciation rates under the 2021 rate agreement.

Gulf Power: Results of Operations

Gulf Power's net income increased $33 million in 2021. During 2021, operating revenues increased $105 million primarily related to higher fuel cost recovery revenues. Operating expenses – net increased $89 million in 2021 primarily related to increases in fuel, purchased power and interchange expense, partly offset by lower O&M expenses.

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NEER: Results of Operations

NEER owns, develops, constructs, manages and operates electric generation facilities in wholesale energy markets in the U.S. and Canada. NEER also provides full energy and capacity requirements services, engages in power and fuel marketing and trading activities, owns, develops, constructs and operates rate-regulated transmission facilities and transmission lines and invests in natural gas, natural gas liquids and oil production and pipeline infrastructure assets. NEER’s net income less net loss attributable to noncontrolling interests for 2021 and 2020 was $599 million and $531 million, respectively, resulting in an increase in 2021 of $68 million. The primary drivers, on an after-tax basis, of the change are in the following table.

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(a)    Reflects after-tax project contributions, including the net effect of deferred income taxes and other benefits associated with PTCs and ITCs for wind, solar and storage projects, as applicable (see Note 1 – Income Taxes and – Sales of Differential Membership Interests and Note 5), but excludes allocation of interest expense or corporate general and administrative expenses. Results from projects and pipelines are included in new investments during the first twelve months of operation or ownership. Project results, including repowered wind projects, are included in existing generation and storage assets and pipeline results are included in gas infrastructure beginning with the thirteenth month of operation or ownership.

(b)    Excludes allocation of interest expense and corporate general and administrative expenses.

(c)    See Overview – Adjusted Earnings for additional information.

New Investments

In 2021, results from new investments increased primarily due to higher earnings, including the net effect of deferred income taxes and other benefits associated with PTCs and ITCs, related to the addition of wind and solar generating projects and battery storage during or after 2020.

The discussion below describes changes in certain line items set forth in NEE's consolidated statements of income as they relate to NEER.

Operating Revenues

Operating revenues for 2021 decreased $1,993 million primarily due to:

•the impact of non-qualifying commodity hedges due primarily to changes in energy prices (approximately $2,510 million of losses during 2021 compared to $244 million of losses for 2020), and

•lower revenues from existing generation and storage assets of $331 million primarily due to the impacts of severe prolonged winter weather in Texas in February 2021 (February 2021 weather event), the absence of revenues of certain wind and solar facilities sold to NEP in October 2021 and lower nuclear revenues, due primarily to the closure of Duane Arnold in August 2020,

partly offset by,

•revenues from new investments of $263 million,

•net increases in revenues of $247 million from the customer supply, proprietary power and gas trading, and gas infrastructure businesses, and

•higher revenues of $56 million from NEET primarily related to the acquisition of GridLiance in 2021.

Operating Expenses – net

Operating expenses – net for 2021 increased $309 million primarily due to an increase in depreciation expense of $116 million primarily related to new investments, higher fuel costs of $98 million and an increase of $73 million in O&M expenses primarily related to bad debt expense associated with the February 2021 weather event (see Note 1 – Credit Losses).

Gains on Disposal of Businesses/Assets – net

In 2021, gains on disposal of businesses/assets – net primarily relate to sales of ownership interests in wind and solar projects to NEP and a third party; in 2020, the amount was primarily related to the sale of the Spain projects in the first quarter of 2020. See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

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Interest Expense

NEER's interest expense for 2021 decreased approximately $292 million primarily reflecting $251 million of favorable impacts related to changes in the fair value of interest rate derivative instruments.

Equity in Earnings (Losses) of Equity Method Investees

NEER recognized $666 million of equity in earnings of equity method investees in 2021 compared to $1,351 million of equity in losses of equity method investees for the prior year. The change for 2021 primarily reflects the absence of an impairment charge related to the investment in Mountain Valley Pipeline of approximately $1.5 billion recorded in 2020 and higher equity in earnings of NEP recorded in 2021 primarily due to changes in the fair value of interest rate derivative instruments. Due to continued legal and regulatory challenges related to Mountain Valley Pipeline, NextEra Energy Resources also recorded an impairment charge in the first quarter of 2022 of approximately $0.8 billion ($0.6 billion after tax). See Note 4 – Nonrecurring Fair Value Measurements.

Tax Credits, Benefits and Expenses

PTCs from wind projects and ITCs from solar and certain wind projects are reflected in NEER’s earnings. PTCs are recognized as wind energy is generated and sold based on a per kWh rate prescribed in applicable federal and state statutes. Reflected in income taxes in NEE's consolidated statements of income are PTCs totaling approximately $90 million and $150 million and ITCs totaling approximately $237 million and $133 million in 2021 and 2020, respectively. A portion of the PTCs and ITCs have been allocated to investors in connection with sales of differential membership interests. See Note 1 – Income Taxes for a discussion of PTCs and ITCs and Note 5.

Corporate and Other: Results of Operations

Corporate and Other at NEE is primarily comprised of the operating results of other business activities, as well as corporate interest income and expenses. Corporate and Other allocates a portion of NEECH's corporate interest expense to NextEra Energy Resources. Interest expense is allocated based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy Resources' subsidiaries.

Corporate and Other's results increased $268 million during 2021 primarily due to favorable after-tax impacts of approximately $370 million, as compared to the prior year, related to non-qualifying hedge activity as a result of changes in the fair value of interest rate derivative instruments. The favorable non-qualifying hedge activity was partly offset by higher interest and refinancing costs incurred in 2021.

LIQUIDITY AND CAPITAL RESOURCES

NEE and its subsidiaries require funds to support and grow their businesses. These funds are used for, among other things, working capital, capital expenditures (see Note 15 – Commitments), investments in or acquisitions of assets and businesses (see Note 6), payment of maturing debt and related derivative obligations (see Note 13 and Note 3) and, from time to time, redemption or repurchase of outstanding debt or equity securities. It is anticipated that these requirements will be satisfied through a combination of cash flows from operations, short- and long-term borrowings, the issuance of short- and long-term debt and, from time to time, equity securities, proceeds from differential membership investors and sales of assets to NEP or third parties (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interest), consistent with NEE’s and FPL’s objective of maintaining, on a long-term basis, a capital structure that will support a strong investment grade credit rating. NEE, FPL and NEECH rely on access to credit and capital markets as significant sources of liquidity for capital requirements and other operations that are not satisfied by operating cash flows. The inability of NEE, FPL and NEECH to maintain their current credit ratings could affect their ability to raise short- and long-term capital, their cost of capital and the execution of their respective financing strategies, and could require the posting of additional collateral under certain agreements.

In October 2015, NEE authorized a program to purchase, from time to time, up to $150 million of common units representing limited partner interests in NEP. Under the program, purchases may be made in amounts, at prices and at such times as NEE or its subsidiaries deem appropriate, all subject to market conditions and other considerations. The purchases may be made in the open market or in privately negotiated transactions. Any purchases will be made in such quantities, at such prices, in such manner and on such terms and conditions as determined by NEE or its subsidiaries in their discretion, based on factors such as market and business conditions, applicable legal requirements and other factors. The common unit purchase program does not require NEE to acquire any specific number of common units and may be modified or terminated by NEE at any time. The purpose of the program is not to cause NEP’s common units to be delisted from the New York Stock Exchange or to cause the common units to be deregistered with the SEC. As of December 31, 2021, the dollar value of units that may yet be purchased by NEE under this program was $114 million. At December 31, 2021, NEE owned a noncontrolling general partner interest in NEP and beneficially owned approximately 55.0% of NEP’s voting power.

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Cash Flows

NEE's sources and uses of cash for 2021, 2020 and 2019 were as follows:

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(a)    2019 amount primarily relates to the acquisition of Gulf Power Company. See Note 6 – Gulf Power Company.

For significant financing activity that occurred in January 2022, see Note 13.

NEE's primary capital requirements are for expanding and enhancing FPL's electric system and generation facilities to continue to provide reliable service to meet customer electricity demands and for funding NEER's investments in independent power and other projects. See Note 15 – Commitments for estimated capital expenditures in 2022 through 2026.

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The following table provides a summary of capital investments for 2021, 2020 and 2019.

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Liquidity

At December 31, 2021, NEE's total net available liquidity was approximately $10.6 billion. The table below provides the components of FPL's and NEECH's net available liquidity at December 31, 2021.

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(a)    Provide for the funding of loans up to the amount of the credit facility and the issuance of letters of credit up to $3,275 million ($650 million for FPL and $2,625 million for NEECH). The entire amount of the credit facilities is available for general corporate purposes and to provide additional liquidity in the event of a loss to the companies’ or their subsidiaries’ operating facilities (including, in the case of FPL, a transmission and distribution property loss). FPL’s syndicated revolving credit facilities are also available to support the purchase of $1,375 million of pollution control, solid waste disposal and industrial development revenue bonds in the event they are tendered by individual bondholders and not remarketed prior to maturity as well as the repayment of approximately $882 million of floating rate notes in the event an individual noteholder requires repayment at specified dates prior to maturity. Approximately $3,120 million of FPL's and $3,889 million of NEECH's syndicated revolving credit facilities expire in 2026.

(b)    Approximately $150 million of NEECH's bilateral revolving credit facilities is available for costs incurred in connection with the development, construction and operations of wind and solar power generation facilities.

(c)    Only available for the issuance of letters of credit.

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At December 31, 2021, 72 banks, located globally, participated in FPL’s and NEECH’s revolving credit facilities, with no one bank providing more than 6% of the combined revolving credit facilities. Pursuant to a 1998 guarantee agreement, NEE guarantees the payment of NEECH’s debt obligations under its revolving credit facilities. In order for FPL or NEECH to borrow or to have letters of credit issued under the terms of their respective revolving credit facilities and, also for NEECH, its letter of credit facilities, FPL, in the case of FPL, and NEE, in the case of NEECH, are required, among other things, to maintain a ratio of funded debt to total capitalization that does not exceed a stated ratio. The FPL and NEECH revolving credit facilities also contain default and related acceleration provisions relating to, among other things, failure of FPL and NEE, as the case may be, to maintain the respective ratio of funded debt to total capitalization at or below the specified ratio. At December 31, 2021, each of NEE and FPL was in compliance with its required ratio.

Capital Support

Guarantees, Letters of Credit, Surety Bonds and Indemnifications (Guarantee Arrangements)

Certain subsidiaries of NEE issue guarantees and obtain letters of credit and surety bonds, as well as provide indemnities, to facilitate commercial transactions with third parties and financings. Substantially all of the guarantee arrangements are on behalf of NEE’s consolidated subsidiaries, as discussed in more detail below. NEE is not required to recognize liabilities associated with guarantee arrangements issued on behalf of its consolidated subsidiaries unless it becomes probable that they will be required to perform. At December 31, 2021, NEE believes that there is no material exposure related to these guarantee arrangements.

NEE subsidiaries issue guarantees related to equity contribution agreements associated with the development, construction and financing of certain power generation facilities, engineering, procurement and construction agreements and equity contributions associated with a natural gas pipeline project under construction and a related natural gas transportation agreement. Commitments associated with these activities are included and/or disclosed in the contracts table in Note 15.

In addition, at December 31, 2021, NEE subsidiaries had approximately $5.2 billion in guarantees related to obligations under purchased power agreements, nuclear-related activities, payment obligations related to PTCs, as well as other types of contractual obligations (see Note 4 – Contingent Consideration and Note 15 – Commitments).

In some instances, subsidiaries of NEE elect to issue guarantees instead of posting other forms of collateral required under certain financing arrangements, as well as for other project-level cash management activities. At December 31, 2021, these guarantees totaled approximately $576 million and support, among other things, cash management activities, including those related to debt service and operations and maintenance service agreements, as well as other specific project financing requirements.

Subsidiaries of NEE also issue guarantees to support customer supply and proprietary power and gas trading activities, including the buying and selling of wholesale and retail energy commodities. At December 31, 2021, the estimated mark-to-market exposure (the total amount that these subsidiaries of NEE could be required to fund based on energy commodity market prices at December 31, 2021) plus contract settlement net payables, net of collateral posted for obligations under these guarantees totaled approximately $1.3 billion.

At December 31, 2021, subsidiaries of NEE also had approximately $3.7 billion of standby letters of credit and approximately $902 million of surety bonds to support certain of the commercial activities discussed above. FPL's and NEECH's credit facilities are available to support the amount of the standby letters of credit.

In addition, as part of contract negotiations in the normal course of business, certain subsidiaries of NEE have agreed and in the future may agree to make payments to compensate or indemnify other parties, including those associated with asset divestitures, for possible unfavorable financial consequences resulting from specified events. The specified events may include, but are not limited to, an adverse judgment in a lawsuit, or the imposition of additional taxes due to a change in tax law or interpretations of the tax law. NEE is unable to estimate the maximum potential amount of future payments under some of these contracts because events that would obligate them to make payments have not yet occurred or, if any such event has occurred, they have not been notified of its occurrence.

NEECH, a 100% owned subsidiary of NEE, provides funding for, and holds ownership interests in, NEE's operating subsidiaries other than FPL. NEE has fully and unconditionally guaranteed certain payment obligations of NEECH, including most of its debt and all of its debentures registered pursuant to the Securities Act of 1933 and commercial paper issuances, as well as most of its payment guarantees and indemnifications, and NEECH has guaranteed certain debt and other obligations of subsidiaries within the NEER segment. Certain guarantee arrangements described above contain requirements for NEECH and FPL to maintain a specified credit rating. For a discussion of credit rating downgrade triggers, see Credit Ratings below.

NEE fully and unconditionally guarantees NEECH debentures pursuant to a guarantee agreement, dated as of June 1, 1999 (1999 guarantee) and NEECH junior subordinated debentures pursuant to an indenture, dated as of September 1, 2006 (2006 guarantee). The 1999 guarantee is an unsecured obligation of NEE and ranks equally and ratably with all other unsecured and unsubordinated indebtedness of NEE. The 2006 guarantee is unsecured and subordinate and junior in right of payment to NEE senior indebtedness (as defined therein). No payment on those junior subordinated debentures may be made under the 2006

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guarantee until all NEE senior indebtedness has been paid in full in certain circumstances. NEE’s and NEECH’s ability to meet their financial obligations are primarily dependent on their subsidiaries’ net income, cash flows and their ability to pay upstream dividends or to repay funds to NEE and NEECH. The dividend-paying ability of some of the subsidiaries is limited by contractual restrictions which are contained in outstanding financing agreements.

Summarized financial information of NEE and NEECH is as follows:

Shelf Registration

In March 2021, NEE, NEECH and FPL filed a shelf registration statement with the SEC for an unspecified amount of securities, which became effective upon filing. The amount of securities issuable by the companies is established from time to time by their respective boards of directors. Securities that may be issued under the registration statement include, depending on the registrant, senior debt securities, subordinated debt securities, junior subordinated debentures, first mortgage bonds, common stock, preferred stock, depositary shares, stock purchase contracts, stock purchase units, warrants and guarantees related to certain of those securities.

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Credit Ratings

NEE’s liquidity, ability to access credit and capital markets, cost of borrowings and collateral posting requirements under certain agreements is dependent on its and its subsidiaries credit ratings. At February 17, 2022, Moody’s Investors Service, Inc. (Moody’s), S&P Global Ratings (S&P) and Fitch Ratings, Inc. (Fitch) had assigned the following credit ratings to NEE, FPL and NEECH:

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(a)    A security rating is not a recommendation to buy, sell or hold securities and should be evaluated independently of any other rating. The rating is subject to revision or withdrawal at any time by the assigning rating organization.

(b)    The outlook indicated by each of Moody's, S&P and Fitch is stable.

(c)    Short-term ratings are presented as all bonds outstanding are currently paying a short-term interest rate. At FPL's election, a portion or all of the bonds may be adjusted to a long-term interest rate.

NEE and its subsidiaries have no credit rating downgrade triggers that would accelerate the maturity dates of outstanding debt. A change in ratings is not an event of default under applicable debt instruments, and while there are conditions to drawing on the credit facilities noted above, the maintenance of a specific minimum credit rating is not a condition to drawing on these credit facilities.

Commitment fees and interest rates on loans under these credit facilities’ agreements are tied to credit ratings. A ratings downgrade also could reduce the accessibility and increase the cost of commercial paper and other short-term debt issuances and borrowings and additional or replacement credit facilities. In addition, a ratings downgrade could result in, among other things, the requirement that NEE subsidiaries post collateral under certain agreements and guarantee arrangements, including, but not limited to, those related to fuel procurement, power sales and purchases, nuclear decommissioning funding, debt-related reserves and trading activities. FPL’s and NEECH’s credit facilities are available to support these potential requirements.

Covenants

NEE's charter does not limit the dividends that may be paid on its common stock. As a practical matter, the ability of NEE to pay dividends on its common stock is dependent upon, among other things, dividends paid to it by its subsidiaries. For example, FPL pays dividends to NEE in a manner consistent with FPL's long-term targeted capital structure. However, the mortgage securing FPL's first mortgage bonds contains provisions which, under certain conditions, restrict the payment of dividends to NEE and the issuance of additional first mortgage bonds. Additionally, in some circumstances, the mortgage restricts the amount of retained earnings that FPL can use to pay cash dividends on its common stock. The restricted amount may change based on factors set out in the mortgage. Other than this restriction on the payment of common stock dividends, the mortgage does not restrict FPL's use of retained earnings. At December 31, 2021, no retained earnings were restricted by these provisions of the mortgage and, in light of FPL's current financial condition and level of earnings, management does not expect that planned financing activities or dividends would be affected by these limitations.

FPL may issue first mortgage bonds under its mortgage subject to its meeting an adjusted net earnings test set forth in the mortgage, which generally requires adjusted net earnings to be at least twice the annual interest requirements on, or at least 10% of the aggregate principal amount of, FPL’s first mortgage bonds including those to be issued and any other non-junior FPL indebtedness. At December 31, 2021, coverage for the 12 months ended December 31, 2021 would have been approximately 9.1 times the annual interest requirements and approximately 3.9 times the aggregate principal requirements. New first mortgage bonds are also limited to an amount equal to the sum of 60% of unfunded property additions after adjustments to offset property retirements, the amount of retired first mortgage bonds or qualified lien bonds and the amount of cash on deposit with the mortgage trustee. At December 31, 2021, FPL could have issued in excess of $30.5 billion of additional first mortgage bonds based on the unfunded property additions and retired first mortgage bonds. At December 31, 2021, no cash was deposited with the mortgage trustee for these purposes.

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In September 2006, NEE and NEECH executed a Replacement Capital Covenant (as amended, September 2006 RCC) in connection with NEECH's offering of $350 million principal amount of Series B Enhanced Junior Subordinated Debentures due 2066 (Series B junior subordinated debentures). The September 2006 RCC is for the benefit of persons that buy, hold or sell a specified series of long-term indebtedness (covered debt) of NEECH (other than the Series B junior subordinated debentures) or, in certain cases, of NEE. NEECH's 3.50% Debentures, Series due April 1, 2029 have been designated as the covered debt under the September 2006 RCC. The September 2006 RCC provides that NEECH may redeem, and NEE or NEECH may purchase, any Series B junior subordinated debentures on or before October 1, 2036, only to the extent that the redemption or purchase price does not exceed a specified amount of proceeds from the sale of qualifying securities, subject to certain limitations described in the September 2006 RCC. Qualifying securities are securities that have equity-like characteristics that are the same as, or more equity-like than, the Series B junior subordinated debentures at the time of redemption or purchase, which are sold within 365 days prior to the date of the redemption or repurchase of the Series B junior subordinated debentures.

In June 2007, NEE and NEECH executed a Replacement Capital Covenant (as amended, June 2007 RCC) in connection with NEECH's offering of $400 million principal amount of its Series C Junior Subordinated Debentures due 2067 (Series C junior subordinated debentures). The June 2007 RCC is for the benefit of persons that buy, hold or sell a specified series of covered debt of NEECH (other than the Series C junior subordinated debentures) or, in certain cases, of NEE. NEECH's 3.50% Debentures, Series due April 1, 2029 have been designated as the covered debt under the June 2007 RCC. The June 2007 RCC provides that NEECH may redeem or purchase, or satisfy, discharge or defease (collectively, defease), and NEE and any majority-owned subsidiary of NEE or NEECH may purchase, any Series C junior subordinated debentures on or before June 15, 2037, only to the extent that the principal amount defeased or the applicable redemption or purchase price does not exceed a specified amount raised from the issuance, during the 365 days prior to the date of that redemption, purchase or defeasance, of qualifying securities that have equity-like characteristics that are the same as, or more equity-like than, the applicable characteristics of the Series C junior subordinated debentures at the time of redemption, purchase or defeasance, subject to certain limitations described in the June 2007 RCC.

New Accounting Rules and Interpretations

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 and other interbank offered rates to alternative reference rates. See Note 1 – Reference Rate Reform.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

NEE’s significant accounting policies are described in Note 1 to the consolidated financial statements, which were prepared under GAAP. Critical accounting policies are those that NEE believes are both most important to the portrayal of its financial condition and results of operations, and require complex, subjective judgments, often as a result of the need to make estimates and assumptions about the effect of matters that are inherently uncertain. Judgments and uncertainties affecting the application of those policies may result in materially different amounts being reported under different conditions or using different assumptions.

NEE considers the following policies to be the most critical in understanding the judgments that are involved in preparing its consolidated financial statements:

Accounting for Derivatives and Hedging Activities

NEE uses derivative instruments (primarily swaps, options, futures and forwards) to manage the physical and financial risks inherent in the purchase and sale of fuel and electricity, as well as interest rate and foreign currency exchange rate risk associated primarily with outstanding and expected future debt issuances and borrowings. In addition, NEE, through NEER, uses derivatives to optimize the value of its power generation and gas infrastructure assets and engages in power and fuel marketing and trading activities to take advantage of expected future favorable price movements.

Nature of Accounting Estimates

Accounting pronouncements require the use of fair value accounting if certain conditions are met, which may require significant judgment to measure the fair value of assets and liabilities. This applies not only to traditional financial derivative instruments, but to any contract having the accounting characteristics of a derivative. As a result, significant judgment must be used in applying derivatives accounting guidance to contracts. In the event changes in interpretation occur, it is possible that contracts that currently are excluded from derivatives accounting rules would have to be recorded on the balance sheet at fair value, with changes in the fair value recorded in the statement of income.

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Assumptions and Accounting Approach

Derivative instruments, when required to be marked to market, are recorded on the balance sheet at fair value using a combination of market and income approaches. Fair values for some of the longer-term contracts where liquid markets are not available are derived through the use of industry-standard valuation techniques, such as internally developed models which estimate the fair value of a contract by calculating the present value of the difference between the contract price and the forward prices. Forward prices represent the price at which a buyer or seller could contract today to purchase or sell a commodity at a future date. The near-term forward market for electricity is generally liquid and therefore the prices in the early years of the forward curves reflect observable market quotes. However, in the later years, the market is much less liquid and forward price curves must be developed using factors including the forward prices for the commodities used as fuel to generate electricity, the expected system heat rate (which measures the efficiency of power plants in converting fuel to electricity) in the region where the purchase or sale takes place, and a fundamental forecast of expected spot prices based on modeled supply and demand in the region. NEE estimates the fair value of interest rate and foreign currency 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 derivative agreements. The assumptions in these models are critical since any changes therein could have a significant impact on the fair value of the derivative.

At FPL, substantially all changes in the fair value of energy derivative transactions 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 clause. See Note 3.

In NEE’s non-rate regulated operations, predominantly NextEra Energy Resources, 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 and the equity method investees’ related activity is recognized in equity in earnings of equity method investees in NEE’s consolidated statements of income.

For interest rate and foreign currency derivative instruments, all changes in the derivatives' fair value 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. NEE estimates the fair value of these derivatives using an income approach based on a discounted cash flows valuation technique utilizing observable inputs.

Certain derivative transactions at NEER are entered into as economic hedges but the transactions do not meet the requirements for hedge accounting, hedge accounting treatment is not elected or hedge accounting has been discontinued. Changes in the fair value of those transactions are marked to market and reported in the consolidated statements of income, resulting in earnings volatility. These changes in fair value are reflected in the non-qualifying hedge category in computing adjusted earnings and could be significant to NEER’s results because the economic offset to the positions are not marked to market. As a consequence, NEE's net income reflects only the movement in one part of economically-linked transactions. For example, a gain (loss) in the non-qualifying hedge category for certain energy derivatives is offset by decreases (increases) in the fair value of related physical asset positions in the portfolio or contracts, which are not marked to market under GAAP. For this reason, NEE’s management views results expressed excluding the unrealized mark-to-market impact of the non-qualifying hedges as a meaningful measure of current period performance. For additional information regarding derivative instruments, see Note 3, Overview and Energy Marketing and Trading and Market Risk Sensitivity.

Accounting for Pension Benefits

NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries. Management believes that, based on actuarial assumptions and the well-funded status of the pension plan, NEE will not be required to make any cash contributions to the qualified pension plan in the near future. The qualified pension plan has a fully funded trust dedicated to providing benefits under the plan. NEE allocates net periodic income associated with the pension plan to its subsidiaries annually using specific criteria.

Nature of Accounting Estimates

For the pension plan, the benefit obligation is the actuarial present value, as of the December 31 measurement date, of all benefits attributed by the pension benefit formula to employee service rendered to that date. The amount of benefit to be paid depends on a number of future events incorporated into the pension benefit formula, including an estimate of the average remaining life of employees/survivors as well as the average years of service rendered. The projected benefit obligation is measured based on assumptions concerning future interest rates and future employee compensation levels. NEE derives pension income from actuarial calculations based on the plan’s provisions and various management assumptions including discount rate, rate of increase in compensation levels and expected long-term rate of return on plan assets.

Assumptions and Accounting Approach

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.

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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 are classified as regulatory assets and liabilities at NEE in accordance with regulatory treatment.

Net periodic pension income is calculated using a number of actuarial assumptions. Those assumptions for the years ended December 31, 2021, 2020 and 2019 include:

In developing these assumptions, NEE evaluated input, including other qualitative and quantitative factors, from its actuaries and consultants, as well as information available in the marketplace. In addition, for the expected long-term rate of return on pension plan assets, NEE considered different models, capital market return assumptions and historical returns for a portfolio with an equity/bond asset mix similar to its pension fund, as well as its pension fund's historical compounded returns. NEE believes that 7.35% is a reasonable long-term rate of return, net of investment management fees, on its pension plan assets. NEE will continue to evaluate all of its actuarial assumptions, including its expected rate of return, at least annually, and will adjust them as appropriate.

NEE utilizes in its determination of pension income a market-related valuation of plan assets. This market-related valuation reduces year-to-year volatility and recognizes investment gains or losses over a five-year period following the year in which they occur. Investment gains or losses for this purpose are the difference between the expected return calculated using the market-related value of plan assets and the actual return realized on those plan assets. Since the market-related value of plan assets recognizes gains or losses over a five-year period, the future value of plan assets will be affected as previously deferred gains or losses are recognized. Such gains and losses together with other differences between actual results and the estimates used in the actuarial valuations are deferred and recognized in determining pension income only to the extent they exceed 10% of the greater of projected benefit obligations or the market-related value of plan assets.

The following table illustrates the effect on net periodic pension income of changing the critical actuarial assumptions discussed above, while holding all other assumptions constant:

NEE also utilizes actuarial assumptions about mortality to help estimate obligations of the pension plan. NEE has adopted the latest revised mortality tables and mortality improvement scales released by the Society of Actuaries, which did not have a material impact on the pension plan's obligation.

See Note 12.

Carrying Value 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.

Nature of Accounting Estimates

The amount of future net cash flows, the timing of the cash flows and the determination of an appropriate interest rate all involve estimates and judgments about future events. In particular, the aggregate amount of cash flows determines whether an impairment exists, and the timing of the cash flows is critical in determining fair value. Because each assessment is based on the facts and circumstances associated with each long-lived asset, the effects of changes in assumptions cannot be generalized.

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Assumptions and Accounting Approach

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.

Carrying Value 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.

Nature of Accounting Estimates

Indicators of a potential impairment include, but are not limited to, a series of operating losses of an investee, the absence of an ability to recover the carrying amount of the investment, the inability of the investee to sustain an earnings capacity and a current fair value of an investment that may be less than its carrying value. If indicators of impairment exist, an estimate of the investment’s fair value will be calculated. Approaches for estimating fair value include, among others, an income approach using a probability-weighted discounted cash flows model and a market approach using an earnings before interest, taxes, depreciation and amortization (EBITDA) multiple model. The probability assigned to each scenario as well as the cash flows and EBITDA multiple identified are critical in determining fair value.

Assumptions and Accounting Approach

An impairment loss is required to be recognized if the impairment is deemed to be other than temporary. Assessment of whether an investment is other-than-temporarily impaired involves, among other factors, consideration of the length of time that the fair value is below the carrying value, current expected performance relative to the expected performance when the investment was initially made, performance relative to peers, industry performance relative to the economy, credit rating, regulatory actions and legal and permitting challenges. If management is unable to reasonably assert that an impairment is temporary or believes that there will not be full recovery of the carrying value of its investment, then the impairment is considered 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.

Decommissioning and Dismantlement

NEE accounts 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.

Nature of Accounting Estimates

The calculation of the future cost of retiring long-lived assets, including nuclear decommissioning and plant dismantlement costs, involves estimating the amount and timing of future expenditures and making judgments concerning whether or not such costs are considered a legal obligation. Estimating the amount and timing of future expenditures includes, among other things, making projections of when assets will be retired and ultimately decommissioned and how costs will escalate with inflation. In addition, NEE also makes interest rate and rate of return projections on its investments in determining recommended funding requirements for nuclear decommissioning costs. Periodically, NEE is required to update these estimates and projections which can affect the annual expense amounts recognized, the liabilities recorded and the annual funding requirements for nuclear decommissioning costs. For example, an increase of 0.25% in the assumed escalation rates for nuclear decommissioning costs would increase NEE’s AROs at December 31, 2021 by approximately $234 million.

Assumptions and Accounting Approach

FPL – For ratemaking purposes, FPL accrues and funds for nuclear plant decommissioning costs over the expected service life of each unit based on studies that are approved by the FPSC. The most recent studies, filed in 2020, reflect, among other things, the expiration dates of the operating licenses for FPL’s nuclear units at the time of the studies. FPL’s portion of the future cost of decommissioning its four nuclear units, including spent fuel storage above what is expected to be refunded by the DOE under a spent fuel settlement agreement, is estimated to be approximately $10.2 billion, or $2.4 billion expressed in 2021 dollars. The ultimate costs of decommissioning reflect the application submitted to the NRC for the extension of St. Lucie Units Nos. 1 and 2 licenses for an additional 20 years.

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FPL accrues the cost of dismantling its other generation plants over the expected service life of each unit based on studies filed with the FPSC. Unlike nuclear decommissioning, dismantlement costs are not funded. The most recent studies became effective January 1, 2022. At December 31, 2021, FPL’s portion of the ultimate cost to dismantle its other generation plants is approximately $2.5 billion, or $1.2 billion expressed in 2021 dollars. The majority of the dismantlement costs are not reported as AROs. FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC. Any differences between the amount of the ARO and the amount recorded for ratemaking purposes are reported as a regulatory asset or liability in accordance with regulatory accounting.

The components of FPL’s decommissioning of nuclear plants, dismantlement of plants and other accrued asset removal costs are as follows:

______________________

(a)    See Note 11.

(b)    Included in noncurrent regulatory liabilities on NEE’s and FPL’s consolidated balance sheets, except for $263 million which is related to interim removal costs and is included in noncurrent regulatory assets as of December 31, 2021. See Note 1 – Rate Regulation.

(c)    Included in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets, except for $118 million and $83 million which are related to other generation plant dismantlement and are included in noncurrent regulatory assets as of December 31, 2021 and 2020, respectively.

(d)    Represents total amount accrued for ratemaking purposes.

NEER – NEER records liabilities for the present value of its expected nuclear plant decommissioning costs which are 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. The liabilities are being accreted using the interest method through the date decommissioning activities are expected to be complete. At December 31, 2021 and 2020, the AROs for decommissioning of NEER’s nuclear plants approximated $599 million and $637 million, respectively. 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 $9.4 billion, or $2.1 billion expressed in 2021 dollars.

See Note 1 – Asset Retirement Obligations and – Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs and Note 11.

Regulatory Accounting

Certain of NEE's businesses are subject to rate regulation which results in the recording of regulatory assets and liabilities. See Note 1 – Rate Regulation for details regarding NEE’s regulatory assets and liabilities.

Nature of Accounting Estimates

Regulatory assets and liabilities represent probable future revenues that will be recovered from or refunded to customers through the ratemaking process. Regulatory assets and liabilities are included in rate base or otherwise earn (pay) a return on investment during the recovery period.

Assumptions and Accounting Approach

Accounting guidance allows regulators to create assets and impose liabilities that would not be recorded by non-rate regulated entities. If NEE's rate-regulated entities, primarily 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 regulators, including the FPSC for FPL, have the authority to disallow recovery of costs that they consider excessive or imprudently incurred. Such costs may include, among others, fuel and O&M expenses, the cost of replacing power lost when generation facilities are unavailable, storm restoration costs and costs associated with the construction or acquisition of new facilities. The continued applicability of regulatory accounting is assessed at each reporting period.

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ENERGY MARKETING AND TRADING AND MARKET RISK SENSITIVITY

NEE and FPL are exposed to risks associated with adverse changes in commodity prices, interest rates and equity prices. Financial instruments and positions affecting the financial statements of NEE and FPL described below are held primarily for purposes other than trading. Market risk is measured as the potential loss in fair value resulting from hypothetical reasonably possible changes in commodity prices, interest rates or equity prices over the next year. Management has established risk management policies to monitor and manage such market risks, as well as credit risks.

Commodity Price Risk

NEE and FPL use derivative instruments (primarily swaps, options, futures and forwards) to manage the physical and financial risks inherent in the purchase and sale of fuel and electricity. In addition, NEE, through NEER, uses derivatives to optimize the value of its power generation and gas infrastructure assets and engages in power and fuel marketing and trading activities to take advantage of expected future favorable price movements. See Critical Accounting Policies and Estimates – Accounting for Derivatives and Hedging Activities and Note 3.

During 2020 and 2021, the changes in the fair value of NEE’s consolidated subsidiaries’ energy contract derivative instruments were as follows:

NEE’s total mark-to-market energy contract net assets (liabilities) at December 31, 2021 shown above are included on the consolidated balance sheets as follows:

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The sources of fair value estimates and maturity of energy contract derivative instruments at December 31, 2021 were as follows:

With respect to commodities, NEE’s Exposure Management Committee (EMC), which is comprised of certain members of senior management, and NEE's chief executive officer are responsible for the overall approval of market risk management policies and the delegation of approval and authorization levels. The EMC and NEE's chief executive officer receive periodic updates on market positions and related exposures, credit exposures and overall risk management activities.

NEE uses a value-at-risk (VaR) model to measure commodity price market risk in its trading and mark-to-market portfolios. The VaR is the estimated loss of market value based on a one-day holding period at a 95% confidence level using historical simulation methodology. The VaR figures are as follows:

______________________

(a)    The VaR figures for the trading portfolio include positions that are marked to market. Taking into consideration offsetting unmarked non-derivative positions, such as physical inventory, the trading VaR figures were approximately $9 million and $3 million at December 31, 2021 and December 31, 2020, respectively.

(b)    Non-qualifying hedges are employed to reduce the market risk exposure to physical assets or contracts which are not marked to market. The VaR figures for the non-qualifying hedges and hedges in FPL cost recovery clauses category do not represent the economic exposure to commodity price movements.

Interest Rate Risk

NEE's and FPL's financial results are exposed to risk resulting from changes in interest rates as a result of their respective outstanding and expected future issuances of debt, investments in special use funds and other investments. NEE and FPL manage their respective interest rate exposure by monitoring current interest rates, entering into interest rate contracts and using a combination of fixed rate and variable rate debt. Interest rate contracts are used to mitigate and adjust interest rate exposure when deemed appropriate based upon market conditions or when required by financing agreements.

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The following are estimates of the fair value of NEE's and FPL's financial instruments that are exposed to interest rate risk:

______________________

(a)    See Notes 3 and 4.

The special use funds of NEE and FPL consist of restricted funds set aside to cover the cost of storm damage for FPL and for the decommissioning of NEE's and FPL's nuclear power plants. See Note 1 – Storm Funds, Storm Reserves and Storm Cost Recovery. A portion of these funds is invested in fixed income debt securities primarily carried at estimated fair value. At FPL, changes in fair value, including any credit losses, result in a corresponding adjustment to the related regulatory asset or liability accounts based on current regulatory treatment. The changes in fair value for NEE's non-rate regulated operations result in a corresponding adjustment to other comprehensive income, except for credit losses and unrealized losses on available for sale securities intended or required to be sold prior to recovery of the amortized cost basis, which are reported in current period earnings. Because the funds set aside by FPL for storm damage could be needed at any time, the related investments are generally more liquid and, therefore, are less sensitive to changes in interest rates. The nuclear decommissioning funds, in contrast, are generally invested in longer-term securities.

At December 31, 2021, NEE had interest rate contracts with a notional amount of approximately $11.2 billion to manage exposure to the variability of cash flows associated with expected future and outstanding debt issuances at NEECH and NEER. See Note 3.

Based upon a hypothetical 10% decrease in interest rates, the fair value of NEE’s net liabilities would increase by approximately $1,440 million ($664 million for FPL) at December 31, 2021.

Equity Price Risk

NEE and FPL are exposed to risk resulting from changes in prices for equity securities. For example, NEE’s nuclear decommissioning reserve funds include marketable equity securities carried at their market value of approximately $5,511 million and $4,726 million ($3,552 million and $3,012 million for FPL) at December 31, 2021 and 2020, respectively. NEE's and FPL’s investment strategy for equity securities in their nuclear decommissioning reserve funds emphasizes marketable securities which are broadly diversified. At December 31, 2021, a hypothetical 10% decrease in the prices quoted on stock exchanges would result in an approximately $520 million ($335 million for FPL) reduction in fair value. For FPL, a corresponding adjustment would be made to the related regulatory asset or liability accounts based on current regulatory treatment, and for NEE’s non-rate regulated operations, a corresponding amount would be 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.

Credit Risk

NEE and its subsidiaries, including FPL, are also exposed to credit risk through their energy marketing and trading operations. Credit risk is the risk that a financial loss will be incurred if a counterparty to a transaction does not fulfill its financial obligation. NEE manages counterparty credit risk for its subsidiaries with energy marketing and trading operations through established policies, including counterparty credit limits, and in some cases credit enhancements, such as cash prepayments, letters of credit, cash and other collateral and guarantees.

Credit risk is also managed through the use of master netting agreements. NEE’s credit department monitors current and forward credit exposure to counterparties and their affiliates, both on an individual and an aggregate basis. For all derivative and contractual transactions, NEE’s energy marketing and trading operations, which include FPL's energy marketing and trading division, are exposed to losses in the event of nonperformance by counterparties to these transactions. Some relevant considerations when assessing NEE’s energy marketing and trading operations’ credit risk exposure include the following:

•Operations are primarily concentrated in the energy industry.

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•Trade receivables and other financial instruments are predominately with energy, utility and financial services related companies, as well as municipalities, cooperatives and other trading companies in the U.S.

•Overall credit risk is managed through established credit policies and is overseen by the EMC.

•Prospective and existing customers are reviewed for creditworthiness based upon established standards, with customers not meeting minimum standards providing various credit enhancements or secured payment terms, such as letters of credit or the posting of margin cash collateral.

•Master netting agreements are used to offset cash and noncash gains and losses arising from derivative instruments with the same counterparty. NEE’s policy is to have master netting agreements in place with significant counterparties.

Based on NEE’s policies and risk exposures related to credit, NEE and FPL do not anticipate a material adverse effect on their financial statements as a result of counterparty nonperformance. At December 31, 2021, NEE's credit risk exposure associated with its energy marketing and trading counterparties, taking into account collateral and contractual netting rights, totaled approximately $1.9 billion ($61 million for FPL), of which approximately 64% (100% for FPL) was with companies that have investment grade credit ratings. With regard to credit risk exposure to counterparties with below investment grade credit ratings, NEE has first lien security positions with respect to approximately 60% of such exposure. For the remaining unsecured positions with counterparties that have below investment grade credit ratings, no one counterparty makes up more than 9% of NEE’s total exposure to below investment grade counterparties. See Notes 1 – Credit Losses, 2 and 3.