10-K

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

☑ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2021

OR

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ________ to ________

Commission File Number	Exact name of registrants as specified in their charters, address of principal executive offices and registrants' telephone number	IRS Employer Identification Number
1-8841	NEXTERA ENERGY, INC.	59-2449419
2-27612	FLORIDA POWER & LIGHT COMPANY	59-0247775

700 Universe Boulevard

Juno Beach, Florida 33408

(561) 694-4000

State or other jurisdiction of incorporation or organization:  Florida

Securities registered pursuant to Section 12(b) of the Act:

Registrants	Title of each class	Trading Symbol(s)	Name of each exchange on which registered
NextEra Energy, Inc.	Common Stock, $0.01 Par Value	NEE	New York Stock Exchange
	4.872% Corporate Units	NEE.PRO	New York Stock Exchange
	5.279% Corporate Units	NEE.PRP	New York Stock Exchange
	6.219% Corporate Units	NEE.PRQ	New York Stock Exchange
Florida Power & Light Company	None

Indicate by check mark if the registrants are well-known seasoned issuers, as defined in Rule 405 of the Securities Act of 1933.

NextEra Energy, Inc.    Yes ☑  No ☐                                                                     Florida Power & Light Company    Yes ☑    No ☐

Indicate by check mark if the registrants are not required to file reports pursuant to Section 13 or Section 15(d) of the Securities Exchange Act of 1934.

NextEra Energy, Inc.    Yes ☐  No ☑                                                                     Florida Power & Light Company    Yes ☐    No ☑

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months, and (2) have been subject to such filing requirements for the past 90 days.

NextEra Energy, Inc.    Yes ☑  No ☐                                                                     Florida Power & Light Company    Yes ☑    No ☐

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S‑T during the preceding 12 months.

NextEra Energy, Inc.    Yes ☑  No ☐                                                                     Florida Power & Light Company    Yes ☑    No ☐

Indicate by check mark whether the registrants are a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company.

NextEra Energy, Inc. Large Accelerated Filer ☑ Accelerated Filer ☐ Non-Accelerated Filer ☐ Smaller Reporting Company ☐ Emerging Growth Company ☐

Florida Power & Light Company Large Accelerated Filer ☐ Accelerated Filer ☐ Non-Accelerated Filer ☑ Smaller Reporting Company ☐ Emerging Growth Company ☐

If an emerging growth company, indicate by check mark if the registrants have elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Securities Exchange Act of 1934. ☐

Indicate by check mark whether each registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☑

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Securities Exchange Act of 1934).  Yes ☐    No ☑

Aggregate market value of the voting and non-voting common equity of NextEra Energy, Inc. held by non-affiliates at June 30, 2021 (based on the closing market price on the Composite Tape on June 30, 2021) was $143,450,834,024.

There was no voting or non-voting common equity of Florida Power & Light Company held by non-affiliates at June 30, 2021.

Number of shares of NextEra Energy, Inc. common stock, $0.01 par value, outstanding at January 31, 2022: 1,962,744,998

Number of shares of Florida Power & Light Company common stock, without par value, outstanding at January 31, 2022, all of which were held, beneficially and of record, by NextEra Energy, Inc.: 1,000

DOCUMENTS INCORPORATED BY REFERENCE

Portions of NextEra Energy, Inc.'s Proxy Statement for the 2022 Annual Meeting of Shareholders are incorporated by reference in Part III hereof.

__________________________________

This combined Form 10-K represents separate filings by NextEra Energy, Inc. and Florida Power & Light Company. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Florida Power & Light Company makes no representations as to the information relating to NextEra Energy, Inc.'s other operations.

Florida Power & Light Company meets the conditions set forth in General Instruction I.(1)(a) and (b) of Form 10-K and is therefore filing this Form with the reduced disclosure format.

DEFINITIONS

Acronyms and defined terms used in the text include the following:

Term	Meaning
AFUDC – equity	equity component of allowance for funds used during construction
Bcf	billion cubic feet
CAISO	California Independent System Operator
capacity clause	capacity cost recovery clause, as established by the FPSC
DOE	U.S. Department of Energy
Duane Arnold	Duane Arnold Energy Center
environmental clause	environmental cost recovery clause, as established by the FPSC
EPA	U.S. Environmental Protection Agency
ERCOT	Electric Reliability Council of Texas
FERC	U.S. Federal Energy Regulatory Commission
Florida Southeast Connection	Florida Southeast Connection, LLC, a wholly owned NextEra Energy Resources subsidiary
FPL	the legal entity, Florida Power & Light Company; beginning January 1, 2022, an operating segment of NEE
FPL segment	through December 31, 2021, FPL, excluding Gulf Power, related purchase accounting adjustments and eliminating entries, and an operating segment of NEE and FPL
FPSC	Florida Public Service Commission
fuel clause	fuel and purchased power cost recovery clause, as established by the FPSC
GAAP	generally accepted accounting principles in the U.S.
Gulf Power	through December 31, 2021, an operating segment of NEE and an operating division and operating segment of FPL
ISO	independent system operator
ISO-NE	ISO New England Inc.
ITC	investment tax credit
kW	kilowatt
kWh	kilowatt-hour(s)
Management's Discussion	Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations
MISO	Midcontinent Independent System Operator
MMBtu	One million British thermal units
mortgage	mortgage and deed of trust dated as of January 1, 1944, from FPL to Deutsche Bank Trust Company Americas, as supplemented and amended
MW	megawatt(s)
MWh	megawatt-hour(s)
NEE	NextEra Energy, Inc.
NEECH	NextEra Energy Capital Holdings, Inc.
NEER	an operating segment comprised of NextEra Energy Resources and NEET
NEET	NextEra Energy Transmission, LLC
NEP	NextEra Energy Partners, LP
NEP OpCo	NextEra Energy Operating Partners, LP
NERC	North American Electric Reliability Corporation
net capacity	net ownership interest in pipeline(s) capacity
net generating capacity	net ownership interest in plant(s) capacity
net generation	net ownership interest in plant(s) generation
Note __	Note __ to consolidated financial statements
NextEra Energy Resources	NextEra Energy Resources, LLC
NRC	U.S. Nuclear Regulatory Commission
NYISO	New York Independent System Operator
O&M expenses	other operations and maintenance expenses in the consolidated statements of income
OEB	Ontario Energy Board
OTC	over-the-counter
OTTI	other than temporary impairment
PJM	PJM Interconnection, LLC
PMI	NextEra Energy Marketing, LLC
Point Beach	Point Beach Nuclear Power Plant
PTC	production tax credit
PUCT	Public Utility Commission of Texas
regulatory ROE	return on common equity as determined for regulatory purposes
RPS	renewable portfolio standards
RTO	regional transmission organization
Sabal Trail	Sabal Trail Transmission, LLC, an entity in which a NextEra Energy Resources subsidiary has a 42.5% ownership interest
Seabrook	Seabrook Station
SEC	U.S. Securities and Exchange Commission
storm protection plan	storm protection plan cost recovery clause, as established by the FPSC
U.S.	United States of America

NEE, FPL, NEECH, NextEra Energy Resources and NEET each has subsidiaries and affiliates with names that may include NextEra Energy, FPL, NextEra Energy Resources, NextEra Energy Transmission, NextEra, FPL Group, FPL Energy, FPLE, NEP and similar references. For convenience and simplicity, in this report the terms NEE, FPL, NEECH, NextEra Energy Resources, NEET and NEER are sometimes used as abbreviated references to specific subsidiaries, affiliates or groups of subsidiaries or affiliates. The precise meaning depends on the context.

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TABLE OF CONTENTS

		Page No.
Definitions		2
Forward-Looking Statements		3
	PART I
Item 1.	Business	4
Item 1A.	Risk Factors	21
Item 1B.	Unresolved Staff Comments	33
Item 2.	Properties	33
Item 3.	Legal Proceedings	33
Item 4.	Mine Safety Disclosures	33
	PART II
Item 5.	Market for Registrants' Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	34
Item 6.	Reserved	34
Item 7.	Management's Discussion and Analysis of Financial Condition and Results of Operations	35
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	55
Item 8.	Financial Statements and Supplementary Data	56
Item 9.	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	112
Item 9A.	Controls and Procedures	112
Item 9B.	Other Information	112
Item 9C.	Disclosure Regarding Foreign Jurisdictions that Prevent Inspections	112
	PART III
Item 10.	Directors, Executive Officers and Corporate Governance	113
Item 11.	Executive Compensation	113
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	113
Item 13.	Certain Relationships and Related Transactions, and Director Independence	113
Item 14.	Principal Accountant Fees and Services	114
	PART IV
Item 15.	Exhibits and Financial Statement Schedules	115
Item 16.	Form 10-K Summary	122
Signatures		123

FORWARD-LOOKING STATEMENTS

This report includes forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Any statements that express, or involve discussions as to, expectations, beliefs, plans, objectives, assumptions, strategies, future events or performance (often, but not always, through the use of words or phrases such as may result, are expected to, will continue, is anticipated, believe, will, could, should, would, estimated, may, plan, potential, future, projection, goals, target, outlook, predict and intend or words of similar meaning) are not statements of historical facts and may be forward looking. Forward-looking statements involve estimates, assumptions and uncertainties. Accordingly, any such statements are qualified in their entirety by reference to, and are accompanied by, important factors included in Part I, Item 1A. Risk Factors (in addition to any assumptions and other factors referred to specifically in connection with such forward-looking statements) that could have a significant impact on NEE's and/or FPL's operations and financial results, and could cause NEE's and/or FPL's actual results to differ materially from those contained or implied in forward-looking statements made by or on behalf of NEE and/or FPL in this combined Form 10-K, in presentations, on their respective websites, in response to questions or otherwise.

Any forward-looking statement speaks only as of the date on which such statement is made, and NEE and FPL undertake no obligation to update any forward-looking statement to reflect events or circumstances, including, but not limited to, unanticipated events, after the date on which such statement is made, unless otherwise required by law. New factors emerge from time to time and it is not possible for management to predict all of such factors, nor can it assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained or implied in any forward-looking statement.

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PART I

Item 1. Business

OVERVIEW

NEE is one of the largest electric power and energy infrastructure companies in North America and a leader in the renewable energy industry. NEE has two principal businesses, FPL and NEER. FPL is the largest electric utility in the state of Florida and one of the largest electric utilities in the U.S. FPL’s strategic focus is centered on investing in generation, transmission and distribution facilities to deliver on its value proposition of low customer bills, high reliability, outstanding customer service and clean energy solutions for the benefit of its more than 5.7 million customers. NEER is the world's largest generator of renewable energy from the wind and sun, as well as a world leader in battery storage. NEER’s strategic focus is centered on the development, construction and operation of long-term contracted assets throughout the U.S. and Canada, primarily consisting of clean energy solutions such as renewable generation facilities and battery storage projects, and electric transmission facilities.

In January 2019, NEE acquired Gulf Power Company, a rate-regulated electric utility engaged in the generation, transmission, distribution and sale of electric energy in northwest Florida. 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. 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 FPL – FPL Regulation – FPL Electric Rate Regulation – Base Rates – Base Rates Effective January 2022 through December 2025). For purposes of discussion herein, the use of the term "FPL" represents FPL the legal entity and beginning January 1, 2022, an operating segment of NEE. Through December 31, 2021, "FPL segment" represents FPL, excluding Gulf Power, and "Gulf Power" represents an operating division of FPL, each operating segments of NEE and FPL.

As described in more detail in the following sections, NEE seeks to create value in its two principal businesses by meeting its customers' needs more economically and more reliably than its competitors. NEE's strategy has resulted in profitable growth over sustained periods at both FPL and NEER. Management seeks to grow each business in a manner consistent with the varying opportunities available to it; however, management believes that the diversification and balance represented by FPL and NEER is a valuable characteristic of the enterprise and recognizes that each business contributes to NEE's financial strength in different ways. FPL and NEER share a common platform with the objective of lowering costs and creating efficiencies for their businesses. NEE and its subsidiaries, with employees totaling approximately 15,000 as of December 31, 2021, continue to develop and implement enterprise-wide initiatives focused on improving productivity, process effectiveness and quality.

As of January 1, 2022, NEE's segments for financial reporting purposes are FPL and NEER. NEECH, a wholly owned subsidiary of NEE, owns and provides funding for NEE's operating subsidiaries, other than FPL and its subsidiaries. NEP, an affiliate of NextEra Energy Resources, acquires, manages and owns contracted clean energy projects with stable, long-term cash flows. See NEER section below for further discussion of NEP. The following diagram depicts NEE's simplified ownership structure:

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FPL

FPL is a rate-regulated electric utility engaged primarily in the generation, transmission, distribution and sale of electric energy in Florida. FPL is the largest electric utility in the state of Florida and one of the largest electric utilities in the U.S. At December 31, 2021, the FPL segment had approximately 28,450 MW of net generating capacity, approximately 77,000 circuit miles of transmission and distribution lines and 696 substations. FPL provides service to its electric customers through integrated transmission and distribution systems that link its generation facilities to its customers. FPL also owns a retail gas business, which serves approximately 117,000 residential and commercial natural gas customers in four counties throughout southern Florida with 3,750 miles of natural gas distribution pipelines.

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. 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 FPL – FPL Regulation – FPL Electric Rate Regulation – Base Rates – Base Rates Effective January 2022 through December 2025 below. FPL serves more than 11 million people through more than 5.7 million customer accounts. The following map shows FPL's service areas and plant locations, which cover most of the east and lower west coasts of Florida and are in eight counties throughout northwest Florida (see FPL Sources of Generation below).

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CUSTOMERS AND REVENUE

FPL's primary source of operating revenues is from its retail customer base; it also serves a limited number of wholesale customers within Florida. The percentage of the FPL segment's operating revenues and customer accounts by customer class were as follows:

For both retail and wholesale customers, the prices (or rates) that FPL may charge are approved by regulatory bodies, by the FPSC in the case of retail customers and by the FERC in the case of wholesale customers. In general, under U.S. and Florida law, regulated rates are intended to cover the cost of providing service, including a reasonable rate of return on invested capital. Since the regulatory bodies have authority to determine the relevant cost of providing service and the appropriate rate of return on capital employed, there can be no guarantee that FPL will be able to earn any particular rate of return or recover all of its costs through regulated rates. See FPL Regulation below.

FPL seeks to maintain attractive rates for its customers. Since rates are largely cost-based, maintaining low rates requires a strategy focused on developing and maintaining a low-cost position, including the implementation of ideas generated from cost savings initiatives. A common benchmark used in the electric power industry for comparing rates across companies is the price of 1,000 kWh of consumption per month for a residential customer. The FPL segment's 2021 average bill for 1,000 kWh of monthly residential usage was well below both the average of reporting electric utilities within Florida and the July 2021 national average (the latest date for which this data is available) as indicated below:

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FRANCHISE AGREEMENTS AND COMPETITION

FPL's service to its electric retail customers is provided primarily under franchise agreements negotiated with municipalities or counties. During the term of a franchise agreement, which is typically 30 years, the municipality or county agrees not to form its own utility, and FPL has the right to offer electric service to residents. At December 31, 2021, the FPL segment held 192 franchise agreements with various municipalities and counties in Florida with varying expiration dates through 2051. These franchise agreements covered approximately 88% of the FPL segment's retail customer base in Florida. At December 31, 2021, the FPL segment also provided service to customers in 11 other municipalities and to 23 unincorporated areas within its service area without franchise agreements pursuant to the general obligation to serve as a public utility. FPL relies upon Florida law for access to public rights of way.

Because any customer may elect to provide his/her own electric services, FPL effectively must compete for an individual customer's business. As a practical matter, few customers provide their own service at the present time since FPL's cost of service is lower than the cost of self-generation for the vast majority of customers. Changing technology, economic conditions and other factors could alter the favorable relative cost position that FPL currently enjoys; however, FPL seeks as a matter of strategy to ensure that it delivers superior value, in the form of low customer bills, high reliability, outstanding customer service and clean energy solutions.

In addition to self-generation by residential, commercial and industrial customers, FPL also faces competition from other suppliers of electrical energy to wholesale customers and from alternative energy sources. In each of 2021, 2020 and 2019, operating revenues from wholesale and industrial electric customers combined represented approximately five percent of the FPL segment's total operating revenues.

For the building of new steam and solar generating capacity of 75 MW or greater, the FPSC requires investor-owned electric utilities, including FPL, to issue a request for proposal (RFP) except when the FPSC determines that an exception from the RFP process is in the public interest. The RFP process allows independent power producers and others to bid to supply the new generating capacity. If a bidder has the most cost-effective alternative, meets other criteria such as financial viability and demonstrates adequate expertise and experience in building and/or operating generating capacity of the type proposed, the investor-owned electric utility would seek to negotiate a purchased power agreement with the selected bidder and request that the FPSC approve the terms of the purchased power agreement and, if appropriate, provide the required authorization for the construction of the bidder's generating capacity.

FPL SOURCES OF GENERATION

At December 31, 2021, the FPL segment's resources for serving load consisted of approximately 28,564 MW of net generating capacity, of which 28,450 MW were from FPL-owned facilities and 114 MW were available through purchased power agreements. FPL owned and operated 30 units with generating capacity of 22,008 MW that primarily use natural gas and 41 solar generation facilities with generating capacity totaling 2,940 MW. In addition, FPL owned, or had undivided interests in, and operated 4 nuclear units with net generating capacity totaling 3,502 MW (see Nuclear Operations below). FPL also develops and constructs battery storage projects, which when combined with its solar projects, serve to enhance its ability to meet customer needs for a nearly firm generation source. At December 31, 2021, the FPL segment had 483 MW of battery storage capacity. FPL customer usage and operating revenues are typically higher during the summer months, largely due to the prevalent use of air conditioning in its service area. Occasionally, unusually cold temperatures during the winter months result in significant increases in electricity usage for short periods of time.

FPL is in the process of modernizing two generation units at its Lauderdale facility to a high-efficiency, clean-burning natural gas unit (Dania Beach Clean Energy Center). The Dania Beach Clean Energy Center is expected to provide approximately 1,200 MW of generating capacity and to be in service by mid-2022. Through 2025, FPL plans to add new solar generation with cost recovery mechanisms through base rates, a Solar Base Rate Adjustment (SoBRA) and SolarTogetherTM (a voluntary community solar program that gives certain FPL electric customers an opportunity to participate directly in the expansion of solar energy and receive credits on their related monthly customer bill). FPL placed approximately 450 MW of solar generating capacity in service in January 2022 and is currently in the process of constructing an additional 1,190 MW of solar generating capacity, which is expected to be placed in service in 2023 (see FPL Regulation – FPL Electric Rate Regulation – Base Rates – Base Rates Effective January 2022 through December 2025 below).

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Fuel Sources

FPL relies upon a mix of fuel sources for its generation facilities, the ability of some of its generation facilities to operate on both natural gas and oil, and on purchased power to maintain the flexibility to achieve a more economical fuel mix in order to respond to market and industry developments.

*approximately 71% has dual fuel capability

Significant Fuel and Transportation Contracts. At December 31, 2021, FPL had the following significant fuel and transportation contracts in place:

•firm transportation contracts with six different transportation suppliers for natural gas pipeline capacity for an aggregate maximum delivery quantity of 2,916,000 MMBtu/day with expiration dates through 2042 (see Note 15 – Contracts);

•several contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel with expiration dates through 2037; and

•short- and medium-term natural gas supply contracts to provide a portion of FPL's anticipated needs for natural gas. The remainder of FPL's natural gas requirements is purchased in the spot market.

Nuclear Operations

At December 31, 2021, FPL owned, or had undivided interests in, and operated the four nuclear units in Florida discussed below. FPL's nuclear units are periodically removed from service to accommodate planned refueling and maintenance outages, including inspections, repairs and certain other modifications. Scheduled nuclear refueling outages require the unit to be removed from service for variable lengths of time.

Facility	FPL's Ownership (MW)	Beginning of Next Scheduled Refueling Outage	Operating License Expiration Date
St. Lucie Unit No. 1	981	September 2022	2036(a)
St. Lucie Unit No. 2	840(b)	February 2023	2043(a)
Turkey Point Unit No. 3	837	April 2023	2052
Turkey Point Unit No. 4	844	March 2022	2053

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(a)    In 2021, FPL filed an application with the NRC to renew both St. Lucie operating licenses for an additional 20 years. License renewals are pending.

(b)    Excludes 147 MW operated by FPL but owned by non-affiliates.

NRC regulations require FPL to submit a plan for decontamination and decommissioning five years before the projected end of plant operation. If the license renewals are approved by the NRC, FPL's plans provide for St. Lucie Unit No. 1 to be shut down in 2056 with decommissioning activities to be integrated with the dismantlement of St. Lucie Unit No. 2 commencing in 2063. Current plans provide for the dismantlement of Turkey Point Units Nos. 3 and 4 with decommissioning activities commencing in 2052 and 2053, respectively.

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FPL's nuclear facilities use both on-site storage pools and dry storage casks to store spent nuclear fuel generated by these facilities, which are expected to provide sufficient storage of spent nuclear fuel that is generated at these facilities through license expiration, as well as through any pending license extensions.

FPL ENERGY MARKETING AND TRADING

FPL's Energy Marketing & Trading division (EMT) buys and sells wholesale energy commodities, such as natural gas, oil and electricity. EMT procures natural gas and oil for FPL's use in power generation and sells excess natural gas, oil and electricity. EMT also uses derivative instruments (primarily swaps, options and forwards) to manage the physical and financial risks inherent in the purchase and sale of fuel and electricity. Substantially all of the results of EMT's activities are passed through to customers in the fuel or capacity clauses. See Management's Discussion – Energy Marketing and Trading and Market Risk Sensitivity and Note 3.

FPL REGULATION

FPL's operations are subject to regulation by a number of federal, state and other organizations, including, but not limited to, the following:

•the FPSC, which has jurisdiction over retail rates, service area, issuances of securities, planning, siting and construction of facilities, among other things;

•the FERC, which oversees the acquisition and disposition of generation, transmission and other facilities, transmission of electricity and natural gas in interstate commerce, proposals to build and operate interstate natural gas pipelines and storage facilities, and wholesale purchases and sales of electric energy, among other things;

•the NERC, which, through its regional entities, establishes and enforces mandatory reliability standards, subject to approval by the FERC, to ensure the reliability of the U.S. electric transmission and generation system and to prevent major system blackouts;

•the NRC, which has jurisdiction over the operation of nuclear power plants through the issuance of operating licenses, rules, regulations and orders; and

•the EPA, which has the responsibility to maintain and enforce national standards under a variety of environmental laws, in some cases delegating authority to state agencies. The EPA also works with industries and all levels of government, including federal and state governments, in a wide variety of voluntary pollution prevention programs and energy conservation efforts.

FPL Electric Rate Regulation

The FPSC sets rates at a level that is intended to allow the utility the opportunity to collect from retail customers total revenues (revenue requirements) equal to its cost of providing service, including a reasonable rate of return on invested capital. To accomplish this, the FPSC uses various ratemaking mechanisms, including, among other things, base rates and cost recovery clauses. Although FPL and Gulf Power Company merged effective January 1, 2021, FPL continued to be regulated as two separate rate making entities until January 1, 2022 when new unified rates and tariffs became effective for the combined utility system (including the former Gulf Power service area). See Base Rates Effective January 2022 through December 2025 below.

Base Rates. In general, the basic costs of providing electric service, other than fuel and certain other costs, are recovered through base rates, which are designed to recover the costs of constructing, operating and maintaining the utility system. These basic costs include O&M expenses, depreciation and taxes, as well as a return on investment in assets used and useful in providing electric service (rate base). At the time base rates are established, the allowed rate of return on rate base approximates the FPSC's determination of the utility's estimated weighted-average cost of capital, which includes its costs for outstanding debt and an allowed return on common equity. The FPSC monitors the utility's actual regulatory ROE through a surveillance report that is filed monthly with the FPSC. The FPSC does not provide assurance that any regulatory ROE will be achieved. Base rates are determined in rate proceedings or through negotiated settlements of those proceedings. Proceedings can occur at the initiative of the utility or upon action by the FPSC. Existing base rates remain in effect until new base rates are approved by the FPSC.

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 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 MW annually of new solar generation through the SoBRA mechanism in each of

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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 kW and will be required to demonstrate that these proposed solar facilities are cost effective.

•FPL's authorized regulatory ROE is 10.60%, with a range of 9.70% to 11.70%. If FPL's earned regulatory ROE falls below 9.70%, FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.70%, any party with standing may seek a review of FPL's retail base rates. If the average 30-year U.S. Treasury rate is 2.49% or greater over a consecutive six-month period, the authorized regulatory ROE will increase to 10.80% with a range of 9.80% to 11.80%. If triggered, the increase in the authorized regulatory ROE will not result in an incremental general base rate increase, but will apply for all other regulatory purposes, including the SoBRA mechanism.

•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 limited to the amortization of $200 million of depreciation reserve surplus during the first year of the 2021 rate agreement.

•FPL is authorized to expand SolarTogether™ 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 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 Note 1 – Storm Funds, Storm Reserves and Storm Cost Recovery.

•If federal or state permanent corporate income tax changes become effective during the term of the 2021 rate agreement, FPL will be able to prospectively adjust base rates after a review by the FPSC.

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.

Base Rates Effective January 2017 through December 2021 – In December 2016, the FPSC issued a final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2016 rate agreement). Key elements of the 2016 rate agreement, which became effective in January 2017, provided for, among other things, the following:

•new retail base rates and charges which resulted in the following increases in annualized retail base revenues:

◦$400 million beginning January 1, 2017;

◦$211 million beginning January 1, 2018; and

◦$200 million beginning April 1, 2019 for a new approximately 1,720 MW natural gas-fired combined-cycle unit in Okeechobee County, Florida (Okeechobee Clean Energy Center) that achieved commercial operation on March 31, 2019;

•additional base rate increases in 2018 through 2020 associated with the addition of approximately 1,200 MW of new solar generating capacity that became operational during that timeframe;

•a regulatory ROE of 10.55% with a range of 9.60% to 11.60%;

•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%; and

•an interim cost recovery mechanism for storm restoration costs. See Note 1 – Storm Funds, Storm Reserves and Storm Cost Recovery.

Cost Recovery Clauses. Cost recovery clauses are designed to permit full recovery of certain costs and provide a return on certain assets allowed to be recovered through various clauses. Cost recovery clause costs are recovered through levelized monthly charges per kWh or kW, depending on the customer's rate class. These cost recovery clause charges are calculated annually based on estimated costs and estimated customer usage for the following year, plus or minus true-up adjustments to reflect the estimated over or under recovery of costs for the current and prior periods. An adjustment to the levelized charges may be approved during the course of a year to reflect revised estimates. FPL recovers costs from customers through the following clauses:

•Fuel – primarily fuel costs, the most significant of the cost recovery clauses in terms of operating revenues (see Note 1 – Rate Regulation);

•Storm Protection Plan – costs associated with an FPSC-approved transmission and distribution storm protection plan, which includes costs for hardening of overhead transmission and distribution lines, undergrounding of certain distribution lines and vegetation management;

•Capacity – primarily certain costs associated with the acquisition of several electric generation facilities (see Note 1 – Rate Regulation);

•Energy Conservation – costs associated with implementing energy conservation programs; and

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•Environmental – certain costs of complying with federal, state and local environmental regulations enacted after April 1993 and costs associated with three of FPL's solar facilities placed in service prior to 2016.

The FPSC has the authority to disallow recovery of costs that it considers excessive or imprudently incurred. These costs may include, among others, fuel and O&M expenses, the cost of replacing power lost when generation units are unavailable, storm restoration costs and costs associated with the construction or acquisition of new facilities.

FERC

The Federal Power Act grants the FERC exclusive ratemaking jurisdiction over wholesale sales of electricity and the transmission of electricity and natural gas in interstate commerce. Pursuant to the Federal Power Act, electric utilities must maintain tariffs and rate schedules on file with the FERC which govern the rates, terms and conditions for the provision of FERC-jurisdictional wholesale power and transmission services. The Federal Power Act also gives the FERC authority to certify and oversee an electric reliability organization with authority to establish and independently enforce mandatory reliability standards applicable to all users, owners and operators of the bulk-power system. See NERC below. Electric utilities are subject to accounting, record-keeping and reporting requirements administered by the FERC. The FERC also places certain limitations on transactions between electric utilities and their affiliates.

NERC

The NERC has been certified by the FERC as an electric reliability organization. The NERC's mandate is to ensure the reliability and security of the North American bulk-power system through the establishment and enforcement of reliability standards approved by FERC. The NERC's regional entities also enforce reliability standards approved by the FERC. FPL is subject to these reliability standards and incurs costs to ensure compliance with continually heightened requirements, and can incur significant penalties for failing to comply with them.

FPL Environmental Regulation

FPL is subject to environmental laws and regulations as described in the NEE Environmental Matters section below. FPL expects to seek recovery through the environmental clause for compliance costs associated with any new environmental laws and regulations.

FPL HUMAN CAPITAL

FPL had approximately 9,700 employees at December 31, 2021, with approximately 31% of these employees represented by the International Brotherhood of Electrical Workers (IBEW), substantially all of which are under collective bargaining agreements that have approximately three-year terms expiring in April 2022 and January 2025.

GULF POWER

Gulf Power became a part of FPL's rate-regulated electric utility system beginning January 1, 2021, but continued to be regulated as a separate ratemaking entity until January 1, 2022 when new unified rates and tariffs became effective for the combined utility system (see FPL – FPL Regulation – FPL Electric Rate Regulation – Base Rates – Base Rates Effective January 2022 through December 2025). Prior to January 1, 2022, Gulf Power operated under a separate base rate settlement agreement that provided for an allowed regulatory ROE of 10.25%, with a range of 9.25% to 11.25%. As of December 31, 2021, Gulf Power served approximately 481,000 customers in eight counties throughout northwest Florida and had approximately 3,500 MW of electric net generating capacity and 9,500 miles of transmission and distribution lines located primarily in Florida, and was subject to similar regulations described in FPL – FPL Regulation above.

On January 1, 2019, NEE completed the acquisition of all of the outstanding common shares of Gulf Power Company under a stock purchase agreement with The Southern Company dated May 20, 2018, as amended, for approximately $4.44 billion in cash consideration and the assumption of approximately $1.3 billion of Gulf Power debt. On January 1, 2021, Gulf Power Company and FPL merged, with FPL as the surviving entity. The FPL segment and Gulf Power continued to be separate operating segments of NEE, as well as FPL, through 2021. See Note 6 – Gulf Power Company and – Merger of FPL and Gulf Power Company for further discussion.

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NEER

NEER, comprised of NEE's competitive energy and rate-regulated transmission businesses, is a diversified clean energy business with a strategy that emphasizes the development, construction and operation of long-term contracted assets with a focus on renewable projects. NEE reports NextEra Energy Resources and NEET, a rate-regulated transmission business, on a combined basis for segment reporting purposes, and the combined segment is referred to as NEER. The NEER segment currently owns, develops, constructs, manages and operates electric generation facilities in wholesale energy markets in the U.S. and Canada. NEER, with approximately 24,600 MW of total net generating capacity at December 31, 2021, is one of the largest wholesale generators of electric power in the U.S., including approximately 24,070 MW of net generating capacity across 38 states and 520 MW of net generating capacity in 4 Canadian provinces. At December 31, 2021, NEER operates facilities, in which it has ownership interests, with a total generating capacity of approximately 30,000 MW. NEER produces the majority of its electricity from clean and renewable sources as described more fully below. In addition, NEER develops and constructs battery storage projects, which when combined with its renewable projects, serve to enhance its ability to meet customer needs for a nearly firm generation source, or as standalone facilities. At December 31, 2021, NEER had net ownership interest in approximately 735 MW of battery storage capacity. NEER is the world's largest generator of renewable energy from the wind and sun based on 2021 MWh produced on a net generation basis, as well as a world leader in battery storage. The NEER segment also owns, develops, constructs and operates rate-regulated transmission facilities in North America. At December 31, 2021, NEER's rate-regulated transmission facilities and transmission lines that connect its electric generation facilities to the electric grid are comprised of approximately 265 substations and 2,680 circuit miles of transmission lines.

NEER also engages in energy-related commodity marketing and trading activities, including entering into financial and physical contracts. These contracts primarily include power and fuel commodities and their related products for the purpose of providing full energy and capacity requirements services, primarily to distribution utilities in certain markets, and offering customized power and fuel and related risk management services to wholesale customers, as well as to hedge the production from NEER's generation assets that is not sold under long-term power supply agreements. In addition, NEER participates in natural gas, natural gas liquids and oil production through operating and non-operating ownership interests, and in pipeline infrastructure construction, management and operations, through either wholly owned subsidiaries or noncontrolling or joint venture interests, hereafter referred to as the gas infrastructure business. NEER also hedges the expected output from its gas infrastructure production assets to protect against price movements.

NEP – NEP acquires, manages and owns contracted clean energy projects with stable long-term cash flows through a limited partner interest in NEP OpCo. NEP's projects include energy projects contributed by or acquired from NextEra Energy Resources, or acquired from third parties, as well as ownership interests in contracted natural gas pipelines acquired from third parties. NextEra Energy Resources' indirect limited partnership interest in NEP OpCo based on the number of outstanding NEP OpCo common units was approximately 54.7% at December 31, 2021. NextEra Energy Resources 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 its project sales to NEP as third-party sales in its consolidated financial statements. See Note 1 – Basis of Presentation. At December 31, 2021, NEP owned, or had an ownership interest in, a portfolio of wind, solar and solar plus battery storage projects with energy project capacity totaling approximately 7,997 MW and contracted natural gas pipelines, all located in the U.S. as further discussed in Generation and Other Operations. NextEra Energy Resources operates essentially all of the energy projects in NEP's portfolio and its ownership interest in the portfolio's capacity was approximately 3,618 MW at December 31, 2021.

GENERATION AND OTHER OPERATIONS

NEER sells products associated with its generation facilities (energy, capacity, renewable energy credits (RECs) and ancillary services) in competitive markets in regions where those facilities are located. Customer transactions may be supplied from NEER generation facilities or from purchases in the wholesale markets, or from a combination thereof. See Markets and Competition below.

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At December 31, 2021, NEER managed or participated in the management of essentially all of the following generation projects, natural gas pipelines and transmission facilities that it wholly owned or in which it had an ownership interest.

Generation Assets and Other Operations

*Primarily natural gas

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Generation Assets

NEER's portfolio of generation assets primarily consist of generation facilities with long-term power sales agreements for substantially all of their capacity and/or energy output. Information related to contracted generation assets at December 31, 2021 was as follows:

•represented approximately 22,658 MW of total net generating capacity;

•weighted-average remaining contract term of the power sales agreements and the remaining life of the PTCs associated with repowered wind facilities of approximately 16 years, based on forecasted contributions to earnings and forecasted amounts of electricity produced by the repowered wind facilities; and

•several contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel for all nuclear units with expiration dates through 2033 (see Note 15 – Contracts).

NEER's merchant generation assets primarily consist of generation facilities that do not have long-term power sales agreements to sell their capacity and/or energy output and therefore require active marketing and hedging. Merchant generation assets at December 31, 2021 represented approximately 1,932 MW of total net generating capacity, including 1,102 MW from nuclear generation and 824 MW from other peak generation facilities, and are primarily located in the Northeast region of the U.S. NEER utilizes swaps, options, futures and forwards to lock in pricing and manage the commodity price risk inherent in power sales and fuel purchases.

NEER Generation Assets Fuel/Technology Mix

NextEra Energy Resources utilized the following mix of fuel sources for generation facilities in which it has an ownership interest:

*Primarily natural gas

Wind Facilities

•located in 20 states in the U.S. and 4 provinces in Canada;

•operated a total generating capacity of 20,531 MW at December 31, 2021;

•ownership interests in a total net generating capacity of 16,517 MW at December 31, 2021;

◦essentially all MW are from contracted wind assets located primarily throughout Texas and the West and Midwest regions of the U.S. and Canada;

◦added approximately 2,008 MW of new generating capacity and repowered wind generating capacity totaling 435 MW in the U.S. in 2021 and sold assets to NEP and third parties totaling approximately 1,500 MW (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests).

Solar Facilities

•located in 29 states in the U.S.;

•operated photovoltaic, distributed generation and solar thermal facilities with a total generating capacity of 4,356 MW at December 31, 2021;

•ownership interests in solar facilities with a total net generating capacity of 3,391 MW at December 31, 2021;

◦essentially all MW are from contracted solar facilities located primarily throughout the West and South regions of the U.S.;

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◦added approximately 728 MW of generating capacity in the U.S. in 2021 and sold assets to NEP and third parties totaling approximately 468 MW (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests).

Nuclear Facilities

At December 31, 2021, NextEra Energy Resources owned, or had undivided interests in, and operated the three nuclear units discussed below. NEER's nuclear units are periodically removed from service to accommodate planned refueling and maintenance outages, including inspections, repairs and certain other modifications. Scheduled nuclear refueling outages require the unit to be removed from service for variable lengths of time.

Facility	Location	Ownership (MW)	Portfolio Category	Next Scheduled Refueling Outage	Operating License Expiration Date
Seabrook	New Hampshire	1,102(a)	Merchant	April 2023	2050
Point Beach Unit No. 1	Wisconsin	595	Contracted(b)	March 2022	2030(c)
Point Beach Unit No. 2	Wisconsin	595	Contracted(b)	March 2023	2033(c)

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(a)    Excludes 147 MW operated by NEER but owned by non-affiliates.

(b)    NEER sells all of the output of Point Beach Units Nos. 1 and 2 under long-term contracts through their current operating license expiration dates.

(c)    In 2020, NEER filed an application with the NRC to renew both Point Beach operating licenses for an additional 20 years. License renewals are pending.

NEER is responsible for all nuclear unit operations and the ultimate decommissioning of the nuclear units, the cost of which is shared on a pro-rata basis by the joint owners for the jointly-owned units. NRC regulations require plant owners to submit a plan for decontamination and decommissioning five years before the projected end of plant operation. NEER's nuclear facilities use both on-site storage pools and dry storage casks to store spent nuclear fuel generated by these facilities, which are expected to provide sufficient storage of spent nuclear fuel that is generated at these facilities through current license expiration, as well as through any pending license extensions.

NEER also owns an approximately 70% interest in Duane Arnold, a nuclear facility located in Iowa that ceased operations in August 2020. NEER submitted a site-specific cost estimate and plan for decontamination and decommissioning to the NRC. All spent nuclear fuel housed onsite is expected to be in long-term dry storage within three years of plant shutdown and until the DOE is able to take possession. NEER estimates that the cost of decommissioning Duane Arnold is fully funded and expects completion by approximately 2080.

Policy Incentives for Renewable Energy Projects

U.S. federal, state and local governments have established various incentives to support the development of renewable energy projects. These incentives include accelerated tax depreciation, PTCs, ITCs, cash grants, tax abatements and RPS programs. Pursuant to the U.S. federal Modified Accelerated Cost Recovery System, wind and solar projects are substantially depreciated for tax purposes over a five-year period even though the useful life of such projects is generally much longer than five years.

Owners of utility-scale wind facilities are eligible to claim an income tax credit (the PTC, or an ITC in lieu of the PTC) upon initially achieving commercial operation. The PTC is determined based on the amount of electricity produced by the wind facility during the first ten years of commercial operation. This incentive was created under the Energy Policy Act of 1992 and has been extended several times. Alternatively, an ITC equal to 30% of the cost of a wind facility may be claimed in lieu of the PTC. Owners of solar facilities are eligible to claim a 30% ITC for new solar facilities. In order to qualify for the PTC (or an ITC in lieu of the PTC) for wind or an ITC for solar, construction of a facility must begin before a specified date and the taxpayer must maintain a continuous program of construction or continuous efforts to advance the project to completion. The Internal Revenue Service (IRS) issued guidance establishing a safe harbor for the continuous efforts and continuous construction requirements. The current guidance provides that the requirements for safe harbor will generally be satisfied if the facility is placed in service no more than six years after the year in which construction of the facility began for a facility that began construction in 2016 through 2019, five years for a facility that began construction in 2020 and four years for a facility that begins construction in 2021 and beyond. Retrofitted wind facilities may re-qualify for PTCs or ITCs pursuant to the 5% safe harbor for the begin construction requirement, as long as the cost basis of the new investment is at least 80% of the facility’s total fair value. Tax credits for qualifying wind and solar projects are subject to the following schedule.

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	Year construction of project begins(a)
	2016		2017		2018		2019		2020		2021		2022		2023		2024 and beyond
PTC(b)	100	%	80	%	60	%	40	%	60	%	60	%	-		-		-
Wind ITC(c)	30	%	24	%	18	%	12	%	18	%	18	%	-		-		-
Solar ITC(d)	30	%	30	%	30	%	30	%	26	%	26	%	26	%	22	%	10	%

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(a)    To qualify for the PTC or an ITC, a project must be placed in service no more than six years after the year in which construction of the project began for a facility that began construction in 2016 – 2019, five years for a facility that began construction in 2020 and four years for a facility that begins construction in 2021 and beyond.

(b)    Percentage of the full PTC available for wind projects that began construction during the applicable year.

(c)    Percentage of eligible project costs that can be claimed as ITC by wind projects that began construction during the applicable year.

(d)    Percentage of eligible project costs that can be claimed as ITC by solar projects that begin construction during the applicable year. ITC is limited to 10% for solar projects not placed in service before January 1, 2026.

Other countries, including Canada, provide for incentives like feed-in-tariffs for renewable energy projects. The feed-in-tariffs promote renewable energy investments by offering long-term contracts to renewable energy producers, typically based on the cost of generation of each technology.

Other Operations

Gas Infrastructure Business – At December 31, 2021, NextEra Energy Resources had ownership interests in natural gas pipelines, the most significant of which are discussed below, and in oil and gas shale formations located primarily in the Midwest and South regions of the U.S.

	Miles of Pipeline	Pipeline Location/Route	Ownership		Total Net Capacity (per day)	In-Service Dates
Texas Pipelines(a)	542	South Texas	52.8%	(b)	2.09 Bcf	1950s – 2015
Sabal Trail(c)	517	Southwestern Alabama to Central Florida	42.5%		0.43 Bcf	June 2017 – May 2020
Florida Southeast Connection(c)	169	Central Florida to South Florida	100%		0.64 Bcf	June 2017
Central Penn Line(d)	191	Northeastern Pennsylvania to Southeastern Pennsylvania	21.3%	(b)	0.39 Bcf	October 2018 – October 2021

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(a)    A NEP portfolio of seven natural gas pipelines, of which a third party owns a 10% interest in a 120-mile pipeline with a daily capacity of approximately 2.3 Bcf. Approximately 1.64 Bcf per day of net capacity is contracted with firm ship-or-pay contracts that have expiration dates ranging from 2022 to 2035.

(b)    Ownership percentage based on NextEra Energy Resources limited partnership interest in NEP OpCo common units.

(c)    See Note 15 – Contracts for a discussion of transportation contracts with FPL.

(d)    NEP has an indirect equity method investment in the Central Penn Line (CPL) which represents an approximately 39% aggregate ownership interest in the CPL.

NEER also has a 31.9% ownership interest in a 303-mile natural gas pipeline that is under construction in West Virginia and Virginia. Completion of construction of the natural gas pipeline is subject to certain conditions, including applicable regulatory approvals and the resolution of legal challenges. See Note 4 – Nonrecurring Fair Value Measurements for a discussion of impairment charges in the first quarter of 2022 and in 2020 and Note 15 – Contracts for a discussion of a transportation contract with a NextEra Energy Resources subsidiary.

Rate-Regulated Transmission – At December 31, 2021, certain entities within the NEER segment had ownership interests in rate-regulated transmission facilities, the most significant of which are discussed below, which are located primarily in ERCOT, CAISO, Southwest Power Pool (SPP), Independent Electricity System Operator (IESO) and NYISO jurisdictions.

	Miles	Substations	Kilovolt	Location	Rate Regulator	Ownership		Actual/Expected In-Service Dates
Operational:
Lone Star	347	9	345	Texas	PUCT	100%		2013
Trans Bay Cable	53	2	200 DC(a)	California	FERC	100%		2010
GridLiance(b)	700	31	69 – 230	Illinois, Kansas, Kentucky, Missouri, Nevada and Oklahoma	FERC	100%	(b)	1960 – 2021
Under Construction:
NextBridge Infrastructure	280	-	230	Ontario, Canada	OEB	50%		First Quarter of 2022
Empire State Line	20	2	345	New York	FERC	100%		December 2021 – Mid-2022

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(a)    Direct current

(b)    Comprised of three FERC-regulated transmission utilities; the assets of which are owned 100% except for a 26-mile transmission line and 5 substations, of which NEET owns a 65% interest.

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Customer Supply and Proprietary Power and Gas Trading – NEER provides commodities-related products to customers, engages in energy-related commodity marketing and trading activities and includes the operations of a retail electricity provider. Through NextEra Energy Resources subsidiary PMI, NEER:

•manages risk associated with fluctuating commodity prices and optimizes the value of NEER's power generation and gas infrastructure production assets through the use of swaps, options, futures and forwards;

•sells output from NEER's plants that is not sold under long-term contracts and procures fuel for use by NEER's generation fleet;

•provides full energy and capacity requirements to customers; and

•markets and trades energy-related commodity products, including power, fuel, renewable attributes and carbon offsets, as well as marketing and trading services to customers.

MARKETS AND COMPETITION

Electricity markets in the U.S. and Canada are regional and diverse in character. All are extensively regulated, and competition in these markets is shaped and constrained by regulation. The nature of the products offered varies based on the specifics of regulation in each region. Generally, in addition to the natural constraints on pricing freedom presented by competition, NEER may also face specific constraints in the form of price caps, or maximum allowed prices, for certain products. NEER's ability to sell the output of its generation facilities may also be constrained by available transmission capacity, which can vary from time to time and can have a significant impact on pricing.

The degree and nature of competition is different in wholesale markets than in retail markets. The majority of NEER's revenues are derived from wholesale electricity markets. Wholesale power generation is a capital-intensive, commodity-driven business with numerous industry participants. NEER primarily competes on the basis of price, but believes the green attributes of NEER's generation assets, its creditworthiness and its ability to offer and manage reliable customized risk solutions to wholesale customers are competitive advantages. Wholesale power generation is a regional business that is highly fragmented relative to many other commodity industries and diverse in terms of industry structure. As such, there is a wide variation in terms of the capabilities, resources, nature and identity of the companies NEER competes with depending on the market. In wholesale markets, customers' needs are met through a variety of means, including long-term bilateral contracts, standardized bilateral products such as full requirements service and customized supply and risk management services.

In general, U.S. and Canadian electricity markets encompass three classes of services: energy, capacity and ancillary services. Energy services relate to the physical delivery of power; capacity services relate to the availability of MW capacity of a power generation asset; and ancillary services are other services that relate to power generation assets, such as load regulation and spinning and non-spinning reserves. The exact nature of these classes of services is defined in part by regional tariffs. Not all regions have a capacity services class, and the specific definitions of ancillary services vary from region to region.

RTOs and ISOs exist throughout much of North America to coordinate generation and transmission across wide geographic areas and to run markets. NEER operates in all RTO and ISO jurisdictions. At December 31, 2021, NEER also had generation facilities with ownership interests in a total net generating capacity of approximately 5,730 MW that fall within reliability regions that are not under the jurisdiction of an established RTO or ISO, including 3,532 MW within the Western Electricity Coordinating Council and 2,051 MW within the SERC Reliability Corporation. Although each RTO and ISO may have differing objectives and structures, some benefits of these entities include regional planning, managing transmission congestion, developing larger wholesale markets for energy and capacity, maintaining reliability and facilitating competition among wholesale electricity providers. NEER has operations that fall within the following RTOs and ISOs:

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NEER competes in different regions to differing degrees, but in general it seeks to enter into long-term bilateral contracts for the full output of its generation facilities. At December 31, 2021, approximately 92% of NEER's net generating capacity was committed under long-term contracts. Where long-term contracts are not in effect, NEER sells the output of its facilities into daily spot markets. In such cases, NEER will frequently enter into shorter term bilateral contracts, typically of less than three years duration, to hedge the price risk associated with selling into a daily spot market. Such bilateral contracts, which may be hedges either for physical delivery or for financial (pricing) offset, serve to protect a portion of the revenue that NEER expects to derive from the associated generation facility. Contracts that serve the economic purpose of hedging some portion of the expected revenue of a generation facility but are not recorded as hedges under GAAP are referred to as “non-qualifying hedges” for adjusted earnings purposes. See Management's Discussion – Overview – Adjusted Earnings.

Certain facilities within the NEER wind and solar generation portfolio produce RECs and other environmental attributes which are typically sold along with the energy from the plants under long-term contracts, or may be sold separately from wind and solar generation not sold under long-term contracts. The purchasing party is solely entitled to the reporting rights and ownership of the environmental attributes.

While the majority of NEER's revenue is derived from the output of its generation facilities, NEER is also an active competitor in several regions in the wholesale full requirements business and in providing structured and customized power and fuel products and services to a variety of customers. In the full requirements service, typically, the supplier agrees to meet the customer's needs for a full range of products for every hour of the day, at a fixed price, for a predetermined period of time, thereby assuming the risk of fluctuations in the customer's volume requirements.

Expanded competition in a frequently changing regulatory environment presents both opportunities and risks for NEER. Opportunities exist for the selective acquisition of generation assets and for the construction and operation of efficient facilities that can sell power in competitive markets. NEER seeks to reduce its market risk by having a diversified portfolio by fuel type and location, as well as by contracting for the future sale of a significant amount of the electricity output of its facilities.

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NEER REGULATION

The energy markets in which NEER operates are subject to domestic and foreign regulation, as the case may be, including local, state and federal regulation, and other specific rules.

At December 31, 2021, essentially all of NEER's operating independent power projects located in the U.S. have received exempt wholesale generator status as defined under the Public Utility Holding Company Act of 2005. Exempt wholesale generators own or operate a facility exclusively to sell electricity to wholesale customers. They are barred from selling electricity directly to retail customers. While projects with exempt wholesale generator status are exempt from various restrictions, each project must still comply with other federal, state and local laws, including, but not limited to, those regarding siting, construction, operation, licensing, pollution abatement and other environmental laws.

Additionally, most of the NEER facilities located in the U.S. are subject to FERC regulations and market rules and the NERC's mandatory reliability standards, all of its facilities are subject to environmental laws and the EPA's environmental regulations, and its nuclear facilities are also subject to the jurisdiction of the NRC. See FPL – FPL Regulation for additional discussion of FERC, NERC, NRC and EPA regulations. Rates of NEER's rate-regulated transmission businesses are set by regulatory bodies as noted in Generation and Other Operations – Generation Assets and Other Operations – Other Operations – Rate-Regulated Transmission. With the exception of facilities located in ERCOT, the FERC has jurisdiction over various aspects of NEER's business in the U.S., including the oversight and investigation of competitive wholesale energy markets, regulation of the transmission and sale of natural gas, and oversight of environmental matters related to natural gas projects and major electricity policy initiatives. The PUCT has jurisdiction, including the regulation of rates and services, oversight of competitive markets, and enforcement of statutes and rules, over NEER facilities located in ERCOT.

Certain entities within the NEER segment and their affiliates are also subject to federal and provincial or regional regulations in Canada related to energy operations, energy markets and environmental standards. In Canada, activities related to owning and operating wind and solar projects and participating in wholesale and retail energy markets are regulated at the provincial level. In Ontario, for example, electric generation facilities must be licensed by the OEB and may also be required to complete registrations and maintain market participant status with the IESO, in which case they must agree to be bound by and comply with the provisions of the market rules for the Ontario electricity market as well as the mandatory reliability standards of the NERC.

In addition, NEER is subject to environmental laws and regulations as described in the NEE Environmental Matters section below. In order to better anticipate potential regulatory changes, NEER continues to actively evaluate and participate in regional market redesigns of existing operating rules for the integration of renewable energy resources and for the purchase and sale of energy commodities.

NEER HUMAN CAPITAL

NEER had approximately 5,200 employees at December 31, 2021. NEER has collective bargaining agreements with the IBEW, the Utility Workers Union of America and the Security Police and Fire Professionals of America, which collectively represent approximately 12% of NEER's employees. The collective bargaining agreements have approximately two- to four-year terms and expire between September 2022 and December 2025.

NEE ENVIRONMENTAL MATTERS

NEE and its subsidiaries, including FPL, are subject to environmental laws and regulations, including extensive federal, state and local environmental statutes, rules and regulations relating to, among others, air quality, water quality and usage, waste management, wildlife protection and historical resources, for the siting, construction and ongoing operations of their facilities. The U.S. government and certain states and regions, as well as the Government of Canada and its provinces, have taken and continue to take certain actions, such as proposing and finalizing regulations or setting targets or goals, regarding the regulation and reduction of greenhouse gas emissions and the increase of renewable energy generation. The environmental laws in the U.S., including, among others, the Endangered Species Act, the Migratory Bird Treaty Act, and the Bald and Golden Eagle Protection Act, provide for the protection of numerous species, including endangered species and/or their habitats, migratory birds and eagles. The environmental laws in Canada, including, among others, the Species at Risk Act, provide for the recovery of wildlife species that are endangered or threatened and the management of species of special concern. Complying with these environmental laws and regulations could result in, among other things, changes in the design and operation of existing facilities and changes or delays in the location, design, construction and operation of new facilities. Failure to comply could result in fines, penalties, criminal sanctions or injunctions. NEE's rate-regulated subsidiaries expect to seek recovery for compliance costs associated with any new environmental laws and regulations, which recovery for FPL would be through the environmental clause.

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WEBSITE ACCESS TO SEC FILINGS

NEE and FPL make their SEC filings, including the annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports, available free of charge on NEE's internet website, www.nexteraenergy.com, as soon as reasonably practicable after those documents are electronically filed with or furnished to the SEC. The information and materials available on NEE's website (or any of its subsidiaries' or affiliates' websites) are not incorporated by reference into this combined Form 10-K.

INFORMATION ABOUT OUR EXECUTIVE OFFICERS(a)

Name	Age	Position	Effective Date
Miguel Arechabala	60	Executive Vice President, Power Generation Division of NEE Executive Vice President, Power Generation Division of FPL	January 1, 2014
Deborah H. Caplan	59	Executive Vice President, Human Resources and Corporate Services of NEE Executive Vice President, Human Resources and Corporate Services of FPL	April 15, 2013
Robert Coffey	58	Executive Vice President, Nuclear Division and Chief Nuclear Officer of NEE Vice President and Chief Nuclear Officer of FPL	June 14, 2021 June 15, 2021
Paul I. Cutler	62	Treasurer of NEE Treasurer of FPL Assistant Secretary of NEE	February 19, 2003 February 18, 2003 December 10, 1997
John W. Ketchum(b)	51	President and Chief Executive Officer of NextEra Energy Resources	March 1, 2019
Rebecca J. Kujawa(b)	46	Executive Vice President, Finance and Chief Financial Officer of NEE Executive Vice President, Finance and Chief Financial Officer of FPL	March 1, 2019
James M. May	45	Vice President, Controller and Chief Accounting Officer of NEE	March 1, 2019
Ronald R. Reagan	53	Executive Vice President, Engineering, Construction and Integrated Supply Chain of NEE Vice President, Engineering and Construction of FPL	January 1, 2020 March 1, 2019
James L. Robo(b)	59	Chairman, President and Chief Executive Officer of NEE Chairman of FPL	December 13, 2013 May 2, 2012
Charles E. Sieving	49	Executive Vice President & General Counsel of NEE Executive Vice President of FPL	December 1, 2008 January 1, 2009
Eric E. Silagy(b)	56	President and Chief Executive Officer of FPL	May 30, 2014

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(a)Information is as of February 17, 2022. Executive officers are elected annually by, and serve at the pleasure of, their respective boards of directors. Except as noted below, each officer has held his/her present position for five years or more and his/her employment history is continuous. Mr. Coffey served as Vice President, Nuclear for FPL from May 2019 to June 2021. He previously was Regional Vice President for FPL's southern fleet from January 2018 to May 2019 and Site Vice President at Point Beach from May 2016 to January 2018. Mr. Ketchum served as Executive Vice President, Finance and Chief Financial Officer of NEE and FPL from March 2016 to February 2019. Ms. Kujawa served as Vice President, Business Management of NextEra Energy Resources from March 2012 to February 2019. Mr. May served as Controller of NextEra Energy Resources from April 2015 to February 2019. Mr. Reagan served as Vice President, Engineering and Construction of NEE from November 2018 to December 2019 and Vice President, Integrated Supply Chain of NEE from October 2012 to November 2018.

(b)The following information was announced January 25, 2022 and is effective March 1, 2022. Mr. Robo was appointed as Executive Chairman of NEE and will cease to serve as President and Chief Executive Officer of NEE and Chairman of FPL. Mr. Ketchum was appointed President and Chief Executive Officer of NEE and will cease to serve as President and Chief Executive Officer of NextEra Energy Resources. Mrs. Kujawa was appointed as President and Chief Executive Officer of NextEra Energy Resources and will cease to serve as Executive Vice President, Finance and Chief Financial Officer of NEE and FPL. T. Kirk Crews II, age 43, was appointed Executive Vice President, Finance and Chief Financial Officer of NEE and FPL. Mr. Crews served as Vice President, Business Management since March 2019 and was Vice President, Controller and Chief Accounting Officer of NEE from September 2016 until March 2019. Mr. Silagy will take on the added responsibility of Chairman of FPL.

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Item 1A. Risk Factors

Risks Relating to NEE's and FPL's Business

The business, financial condition, results of operations and prospects of NEE and FPL are subject to a variety of risks, many of which are beyond the control of NEE and FPL. These risks, as well as additional risks and uncertainties either not presently known or that are currently believed to not be material to the business, may materially adversely affect the business, financial condition, results of operations and prospects of NEE and FPL and may cause actual results of NEE and FPL to differ substantially from those that NEE or FPL currently expects or seeks. In that event, the market price for the securities of NEE or FPL could decline. Accordingly, the risks described below should be carefully considered together with the other information set forth in this report and in future reports that NEE and FPL file with the SEC.

Regulatory, Legislative and Legal Risks

NEE's and FPL's business, financial condition, results of operations and prospects may be materially adversely affected by the extensive regulation of their business.

The operations of NEE and FPL are subject to complex and comprehensive federal, state and other regulation. This extensive regulatory framework, portions of which are more specifically identified in the following risk factors, regulates, among other things and to varying degrees, NEE's and FPL's industry, businesses, rates and cost structures, operation and licensing of nuclear power facilities, planning, construction and operation of electric generation, transmission and distribution facilities and natural gas and oil production, natural gas, oil and other fuel transportation, processing and storage facilities, acquisition, disposal, depreciation and amortization of facilities and other assets, decommissioning costs and funding, service reliability, wholesale and retail competition, and commodities trading and derivatives transactions. In their business planning and in the management of their operations, NEE and FPL must address the effects of regulation on their business and any inability or failure to do so adequately could have a material adverse effect on their business, financial condition, results of operations and prospects.

NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected if they are unable to recover in a timely manner any significant amount of costs, a return on certain assets or a reasonable return on invested capital through base rates, cost recovery clauses, other regulatory mechanisms or otherwise.

FPL operates as an electric utility and is subject to the jurisdiction of the FPSC over a wide range of business activities, including, among other items, the retail rates charged to its customers through base rates and cost recovery clauses, the terms and conditions of its services, procurement of electricity for its customers and fuel for its plant operations, issuances of securities, and aspects of the siting, planning, construction and operation of its generation plants and transmission and distribution systems for the sale of electric energy. The FPSC has the authority to disallow recovery by FPL of costs that it considers excessive or imprudently incurred and to determine the level of return that FPL is permitted to earn on invested capital. The regulatory process, which may be adversely affected by the political, regulatory, operational and economic environment in Florida and elsewhere, limits or could otherwise adversely impact FPL's earnings. The regulatory process also does not provide any assurance as to achievement of authorized or other earnings levels, or that FPL will be permitted to earn an acceptable return on capital investments it wishes to make. NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected if any material amount of costs, a return on certain assets or a reasonable return on invested capital cannot be recovered through base rates, cost recovery clauses, other regulatory mechanisms or otherwise. Certain other subsidiaries of NEE are utilities subject to the jurisdiction of their regulators and are subject to similar risks.

Regulatory decisions that are important to NEE and FPL may be materially adversely affected by political, regulatory, operational and economic factors.

The local and national political, regulatory and economic environment has had, and may in the future have, an adverse effect on regulatory decisions with negative consequences for NEE and FPL. These decisions, which may come from any level of government, may require, for example, FPL or NEER to cancel or delay planned development activities, to reduce or delay other planned capital expenditures or to pay for investments or otherwise incur costs that it may not be able to recover through rates or otherwise, each of which could have a material adverse effect on the business, financial condition, results of operations and prospects of NEE and FPL.

FPL's use of derivative instruments could be subject to prudence challenges and, if found imprudent, could result in disallowances of cost recovery for such use by the FPSC.

The FPSC engages in an annual prudence review of FPL's use of derivative instruments in its risk management fuel procurement program and should it find any such use to be imprudent, the FPSC could deny cost recovery for such use by FPL. Such an outcome could have a material adverse effect on FPL's business, financial condition, results of operations and prospects.

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Any reductions or modifications to, or the elimination of, governmental incentives or policies that support utility scale renewable energy, including, but not limited to, tax laws, policies and incentives, RPS and feed-in-tariffs, or the imposition of additional taxes, tariffs, duties or other assessments on renewable energy or the equipment necessary to generate or deliver it, could result in, among other items, the lack of a satisfactory market for the development and/or financing of new renewable energy projects, NEER abandoning the development of renewable energy projects, a loss of NEER's investments in renewable energy projects and reduced project returns, any of which could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.

NEER depends heavily on government policies that support utility scale renewable energy and enhance the economic feasibility of developing and operating wind and solar energy projects in regions in which NEER operates or plans to develop and operate renewable energy facilities. The federal government, a majority of state governments in the U.S. and portions of Canada provide incentives, such as tax incentives, RPS or feed-in-tariffs, that support or are designed to support the sale of energy from utility scale renewable energy facilities, such as wind and solar energy facilities. At the same time, the U.S. government generally has not taken action to materially burden the international supply chain that has been important to the development of renewable energy facilities at acceptable prices. As a result of budgetary constraints, political factors or otherwise, governments from time to time may review their laws and policies that support, or do not overly burden, the development and operation of renewable energy facilities and, instead, consider actions that would make the laws and policies less conducive to the development and operation of renewable energy facilities. Any reductions or modifications to, or the elimination of, governmental incentives or policies that support renewable energy or the imposition of additional taxes, tariffs, duties or other assessments on renewable energy or the equipment necessary to generate or deliver it, could result in, among other items, the lack of a satisfactory market for the development and/or financing of new renewable energy projects, NEER abandoning the development of renewable energy projects, a loss of NEER's investments in the projects and reduced project returns, any of which could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.

NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected as a result of new or revised laws or regulations or interpretations of these laws and regulations.

NEE's and FPL's business is influenced by various legislative and regulatory initiatives, including, but not limited to, new or revised laws, including international trade laws, regulations and interpretations, constitutional ballot and regulatory initiatives regarding deregulation or restructuring of the energy industry, regulation of the commodities trading and derivatives markets, and regulation of environmental matters, such as regulation of air emissions, regulation of water consumption and water discharges, and regulation of gas and oil infrastructure operations, as well as associated environmental permitting. Changes in the nature of the regulation of NEE's and FPL's business could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects. NEE and FPL are unable to predict future legislative or regulatory changes, including through constitutional ballot initiatives or changed legal or regulatory interpretations, although any such changes may increase costs and competitive pressures on NEE and FPL, which could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

FPL has limited competition in the Florida market for retail electricity customers. Any changes in Florida law or regulation, whether through new or modified legislation or regulation or through citizen-approved state constitutional ballot initiatives, which introduce competition in the Florida retail electricity market, such as government incentives that facilitate the installation of solar generation facilities on residential or other rooftops at below cost or that are otherwise subsidized by non-participants, or would permit third-party sales of electricity, could have a material adverse effect on FPL's business, financial condition, results of operations and prospects. There can be no assurance that FPL will be able to respond adequately to such regulatory changes, which could have a material adverse effect on FPL's business, financial condition, results of operations and prospects.

NEER is subject to FERC rules related to transmission that are designed to facilitate competition in the wholesale market on practically a nationwide basis by providing greater certainty, flexibility and more choices to wholesale power customers. NEE cannot predict the impact of changing FERC rules or the effect of changes in levels of wholesale supply and demand, which are typically driven by factors beyond NEE's control. There can be no assurance that NEER will be able to respond adequately or sufficiently quickly to such rules and developments, or to any changes that reverse or restrict the competitive restructuring of the energy industry in those jurisdictions in which such restructuring has occurred. Any of these events could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.

NEE and FPL are subject to numerous environmental laws, regulations and other standards that may result in capital expenditures, increased operating costs and various liabilities, and may require NEE and FPL to limit or eliminate certain operations.

NEE and FPL are subject to domestic environmental laws, regulations and other standards, including, but not limited to, extensive federal, state and local environmental statutes, rules and regulations relating to air quality, water quality and usage, soil quality, climate change, emissions of greenhouse gases, including, but not limited to, carbon dioxide, waste management, hazardous wastes, marine, avian and other wildlife mortality and habitat protection, historical artifact preservation, natural resources, health (including, but not limited to, electric and magnetic fields from power lines and substations), safety and RPS, that could, among other things, prevent or delay the development of power generation, power or natural gas transmission, or other infrastructure projects, restrict or enjoin the output of some existing facilities, limit the availability and use of some fuels

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required for the production of electricity, require additional pollution control equipment, and otherwise increase costs, increase capital expenditures and limit or eliminate certain operations. Certain subsidiaries of NEE are also subject to foreign environmental laws, regulations and other standards and, as such, are subject to similar risks.

There are significant capital, operating and other costs associated with compliance with these environmental statutes, rules and regulations, and those costs could be even more significant in the future as a result of new requirements and stricter or more expansive application of existing environmental laws and regulations.

Violations of current or future laws, rules, regulations or other standards could expose NEE and FPL to regulatory and legal proceedings, disputes with, and legal challenges by, governmental entities and third parties, and potentially significant civil fines, criminal penalties and other sanctions, such as restrictions on how NEER develops, sites and operates wind facilities. These violations could result in, without limitation, litigation regarding property damage, personal injury, common law nuisance and enforcement by citizens or governmental authorities of environmental requirements. For example, the DOJ has alleged that certain NEER subsidiaries have violated the Migratory Bird Treaty Act (MBTA) and/or the Bald and Golden Eagle Protection Act (BGEPA) as a result of accidental collisions of eagles into wind turbines at the NEER subsidiaries’ wind facilities without subsidiaries having permits under BGEPA for those activities. If NEER is unsuccessful in reaching a satisfactory settlement of this issue with the DOJ or if additional eagles perish in collisions with wind turbines at NEER’s facilities without NEER having obtained permits for those activities, NEER or its subsidiaries may face criminal prosecution under these laws.

NEE's and FPL's business could be negatively affected by federal or state laws or regulations mandating new or additional limits on the production of greenhouse gas emissions.

Federal or state laws or regulations may be adopted that would impose new or additional limits on the emissions of greenhouse gases, including, but not limited to, carbon dioxide and methane, from electric generation units using fuels like coal and natural gas. The potential effects of greenhouse gas emission limits on NEE's and FPL's electric generation units are subject to significant uncertainties based on, among other things, the timing of the implementation of any new requirements, the required levels of emission reductions, the nature of any market-based or tax-based mechanisms adopted to facilitate reductions, the relative availability of greenhouse gas emission reduction offsets, the development of cost-effective, commercial-scale carbon capture and storage technology and supporting regulations and liability mitigation measures, and the range of available compliance alternatives.

While NEE's and FPL's electric generation portfolio emits greenhouse gases at a lower rate of emissions than most of the U.S. electric generation sector, the results of operations of NEE and FPL could be materially adversely affected to the extent that new federal or state laws or regulations impose any new greenhouse gas emission limits. Any future limits on greenhouse gas emissions could:

•create substantial additional costs in the form of taxes or emissions allowances;

•make some of NEE's and FPL's electric generation units uneconomical to operate in the long term;

•require significant capital investment in carbon capture and storage technology, fuel switching, or the replacement of high-emitting generation facilities with lower-emitting generation facilities; or

•affect the availability or cost of fuel, such as natural gas.

There can be no assurance that NEE or FPL would be able to completely recover any such costs or investments, which could have a material adverse effect on their business, financial condition, results of operations and prospects.

Extensive federal regulation of the operations and businesses of NEE and FPL exposes NEE and FPL to significant and increasing compliance costs and may also expose them to substantial monetary penalties and other sanctions for compliance failures.

NEE's and FPL's operations and businesses are subject to extensive federal regulation, which generally imposes significant and increasing compliance costs on their operations and businesses. Additionally, any actual or alleged compliance failures could result in significant costs and other potentially adverse effects of regulatory investigations, proceedings, settlements, decisions and claims, including, among other items, potentially significant monetary penalties. As an example, under the Energy Policy Act of 2005, NEE and FPL, as owners and operators of bulk-power transmission systems and/or electric generation facilities, are subject to mandatory reliability standards. Compliance with these mandatory reliability standards may subject NEE and FPL to higher operating costs and may result in increased capital expenditures. If FPL or NEE is found not to be in compliance with these standards, they may incur substantial monetary penalties and other sanctions. Both the costs of regulatory compliance and the costs that may be imposed as a result of any actual or alleged compliance failures could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

Changes in tax laws, guidance or policies, including but not limited to changes in corporate income tax rates, as well as judgments and estimates used in the determination of tax-related asset and liability amounts, could materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.

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NEE's and FPL's provision for income taxes and reporting of tax-related assets and liabilities require significant judgments and the use of estimates. Amounts of tax-related assets and liabilities involve judgments and estimates of the timing and probability of recognition of income, deductions and tax credits, including, but not limited to, estimates for potential adverse outcomes regarding tax positions that have been taken and the ability to utilize tax benefit carryforwards, such as net operating loss and tax credit carryforwards. Actual income taxes could vary significantly from estimated amounts due to the future impacts of, among other things, changes in tax laws, guidance or policies, including changes in corporate income tax rates, the financial condition and results of operations of NEE and FPL, and the resolution of audit issues raised by taxing authorities. These factors, including the ultimate resolution of income tax matters, may result in material adjustments to tax-related assets and liabilities, which could materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.

NEE's and FPL's business, financial condition, results of operations and prospects may be materially adversely affected due to adverse results of litigation.

NEE's and FPL's business, financial condition, results of operations and prospects may be materially affected by adverse results of litigation. Unfavorable resolution of legal or administrative proceedings in which NEE or FPL is involved or other future legal or administrative proceedings may have a material adverse effect on the business, financial condition, results of operations and prospects of NEE and FPL.

Development and Operational Risks

NEE's and FPL's business, financial condition, results of operations and prospects could suffer if NEE and FPL do not proceed with projects under development or are unable to complete the construction of, or capital improvements to, electric generation, transmission and distribution facilities, gas infrastructure facilities or other facilities on schedule or within budget.

NEE's and FPL's ability to proceed with projects under development and to complete construction of, and capital improvement projects for, their electric generation, transmission and distribution facilities, gas infrastructure facilities and other facilities on schedule and within budget may be adversely affected by escalating costs for materials and labor and regulatory compliance, inability to obtain or renew necessary licenses, rights-of-way, permits or other approvals on acceptable terms or on schedule, disputes involving contractors, labor organizations, land owners, governmental entities, environmental groups, Native American and aboriginal groups, lessors, joint venture partners and other third parties, negative publicity, transmission interconnection issues, supply chain disruptions and other factors. For example, the ability of NEE and FPL to develop solar generation facilities is dependent on the international supply chain for solar panels and associated equipment, and regulatory actions have caused minor, and could in the future cause material, disruptions in the ability of NEE and FPL to acquire solar panels on time and at acceptable costs. If any development project or construction or capital improvement project is not completed, is delayed or is subject to cost overruns, certain associated costs may not be approved for recovery or otherwise be recoverable through regulatory mechanisms that may be available, and NEE and FPL could become obligated to make delay or termination payments or become obligated for other damages under contracts, could experience the loss of tax credits or tax incentives, or delayed or diminished returns, and could be required to write off all or a portion of their investment in the project. Any of these events could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

NEE and FPL face risks related to project siting, financing, construction, permitting, governmental approvals and the negotiation of project development agreements that may impede their development and operating activities.

NEE and FPL own, develop, construct, manage and operate electric generation and transmission facilities and natural gas transmission facilities. A key component of NEE's and FPL's growth is their ability to construct and operate generation and transmission facilities to meet customer needs. As part of these operations, NEE and FPL must periodically apply for licenses and permits from various local, state, federal and other regulatory authorities and abide by their respective conditions. Should NEE or FPL be unsuccessful in obtaining necessary licenses or permits on acceptable terms or resolving third-party challenges to such licenses or permits, should there be a delay in obtaining or renewing necessary licenses or permits or should regulatory authorities initiate any associated investigations or enforcement actions or impose related penalties or disallowances on NEE or FPL, NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected. Any failure to negotiate successful project development agreements for new facilities with third parties could have similar results.

The operation and maintenance of NEE's and FPL's electric generation, transmission and distribution facilities, gas infrastructure facilities, retail gas distribution system in Florida and other facilities are subject to many operational risks, the consequences of which could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

NEE's and FPL's electric generation, transmission and distribution facilities, gas infrastructure facilities, retail gas distribution system in Florida and other facilities are subject to many operational risks. Operational risks could result in, among other things, lost revenues due to prolonged outages, increased expenses due to monetary penalties or fines for compliance failures or legal claims, liability to third parties for property and personal injury damage or loss of life, a failure to perform under applicable power sales agreements or other agreements and associated loss of revenues from terminated agreements or liability for liquidated

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damages under continuing agreements, and replacement equipment costs or an obligation to purchase or generate replacement power at higher prices.

Uncertainties and risks inherent in operating and maintaining NEE's and FPL's facilities include, but are not limited to:

•risks associated with facility start-up operations, such as whether the facility will achieve projected operating performance on schedule and otherwise as planned;

•failures in the availability, acquisition or transportation of fuel or other necessary supplies;

•the impact of unusual or adverse weather conditions and natural disasters, including, but not limited to, hurricanes, tornadoes, extreme temperatures, icing events, floods, earthquakes and droughts;

•performance below expected or contracted levels of output or efficiency;

•breakdown or failure, including, but not limited to, explosions, fires, leaks or other major events, of equipment, transmission or distribution systems or pipelines;

•availability of replacement equipment;

•risks of property damage, human injury or loss of life from energized equipment, hazardous substances or explosions, fires, leaks or other events, especially where facilities are located near populated areas;

•potential environmental impacts of gas infrastructure operations;

•availability of adequate water resources and ability to satisfy water intake and discharge requirements;

•inability to identify, manage properly or mitigate equipment defects in NEE's and FPL's facilities;

•use of new or unproven technology;

•risks associated with dependence on a specific type of fuel or fuel source, such as commodity price risk, availability of adequate fuel supply and transportation, and lack of available alternative fuel sources;

•increased competition due to, among other factors, new facilities, excess supply, shifting demand and regulatory changes; and

•insufficient insurance, warranties or performance guarantees to cover any or all lost revenues or increased expenses from the foregoing.

NEE's and FPL's business, financial condition, results of operations and prospects may be negatively affected by a lack of growth or slower growth in the number of customers or in customer usage.

Growth in customer accounts and growth of customer usage each directly influence the demand for electricity and the need for additional power generation and power delivery facilities, as well as the need for energy-related commodities such as natural gas. Customer growth and customer usage are affected by a number of factors outside the control of NEE and FPL, such as mandated energy efficiency measures, demand side management requirements, and economic and demographic conditions, such as population changes, job and income growth, housing starts, new business formation and the overall level of economic activity. A lack of growth, or a decline, in the number of customers or in customer demand for electricity or natural gas and other fuels may cause NEE and FPL to fail to fully realize the anticipated benefits from significant investments and expenditures and could have a material adverse effect on NEE's and FPL's growth, business, financial condition, results of operations and prospects.

NEE's and FPL's business, financial condition, results of operations and prospects can be materially adversely affected by weather conditions, including, but not limited to, the impact of severe weather.

Weather conditions directly influence the demand for electricity and natural gas and other fuels and affect the price of energy and energy-related commodities. In addition, severe weather and natural disasters, such as hurricanes, floods, tornadoes, droughts, extreme temperatures, icing events and earthquakes, can be destructive and cause power outages and property damage, reduce revenue, affect the availability of fuel and water, and require NEE and FPL to incur additional costs, for example, to restore service and repair damaged facilities, to obtain replacement power and to access available financing sources. Furthermore, NEE's and FPL's physical plants could be placed at greater risk of damage should changes in the global climate produce unusual variations in temperature and weather patterns, resulting in more intense, frequent and extreme weather events, abnormal levels of precipitation and, particularly relevant to FPL, a change in sea level. FPL operates in the east and lower west coasts of Florida and in northwest Florida, areas that historically have been prone to severe weather events, such as hurricanes. A disruption or failure of electric generation, transmission or distribution systems or natural gas production, transmission, storage or distribution systems in the event of a hurricane, tornado or other severe weather event, or otherwise, could prevent NEE and FPL from operating their business in the normal course and could result in any of the adverse consequences described above. Additionally, the actions taken to address the potential for severe weather such as additional winterizing of critical equipment and infrastructure, modifying or alternating plant operations and expanding load shedding options could result in significant increases in costs. Any of the foregoing could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

At FPL and other businesses of NEE where cost recovery is available, recovery of costs to restore service, to repair damaged facilities or for other actions to address severe weather is or may be subject to regulatory approval, and any determination by the regulator not to permit timely and full recovery of the costs incurred could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

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Changes in weather can also affect the production of electricity at power generation facilities, including, but not limited to, NEER's wind and solar facilities. For example, the level of wind resource affects the revenue produced by wind generation facilities. Because the levels of wind and solar resources are variable and difficult to predict, NEER's results of operations for individual wind and solar facilities specifically, and NEE's results of operations generally, may vary significantly from period to period, depending on the level of available resources. To the extent that resources are not available at planned levels, the financial results from these facilities may be less than expected.

Threats of terrorism and catastrophic events that could result from terrorism, cyberattacks, or individuals and/or groups attempting to disrupt NEE's and FPL's business, or the businesses of third parties, may materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.

NEE and FPL are subject to the potentially adverse operating and financial effects of terrorist acts and threats, as well as cyberattacks and other disruptive activities of individuals or groups. There have been cyberattacks within the energy industry on energy infrastructure such as substations, gas pipelines and related assets in the past and there may be such attacks in the future. NEE's and FPL's generation, transmission and distribution facilities, fuel storage facilities, information technology systems and other infrastructure facilities and systems could be direct targets of, or otherwise be materially adversely affected by, such activities.

Terrorist acts, cyberattacks or other similar events affecting NEE's and FPL's systems and facilities, or those of third parties on which NEE and FPL rely, could harm NEE's and FPL's business, for example, by limiting their ability to generate, purchase or transmit power, natural gas or other energy-related commodities, by limiting their ability to bill customers and collect and process payments, and by delaying their development and construction of new generation, distribution or transmission facilities or capital improvements to existing facilities. These events, and governmental actions in response, could result in a material decrease in revenues, significant additional costs (for example, to repair assets, implement additional security requirements or maintain or acquire insurance), significant fines and penalties, and reputational damage, could materially adversely affect NEE's and FPL's operations (for example, by contributing to disruption of supplies and markets for natural gas, oil and other fuels), and could impair NEE's and FPL's ability to raise capital (for example, by contributing to financial instability and lower economic activity). In addition, the implementation of security guidelines and measures has resulted in and is expected to continue to result in increased costs. Such events or actions may materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.

The ability of NEE and FPL to obtain insurance and the terms of any available insurance coverage could be materially adversely affected by international, national, state or local events and company-specific events, as well as the financial condition of insurers. NEE's and FPL's insurance coverage does not provide protection against all significant losses.

Insurance coverage may not continue to be available or may not be available at rates or on terms similar to those presently available to NEE and FPL. The ability of NEE and FPL to obtain insurance and the terms of any available insurance coverage could be materially adversely affected by international, national, state or local events and company-specific events, as well as the financial condition of insurers. If insurance coverage is not available or obtainable on acceptable terms, NEE or FPL may be required to pay costs associated with adverse future events. NEE and FPL generally are not fully insured against all significant losses. For example, FPL is not fully insured against hurricane-related losses, but could instead seek recovery of such uninsured losses from customers subject to approval by the FPSC, to the extent losses exceed restricted funds set aside to cover the cost of storm damage. A loss for which NEE or FPL is not fully insured could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

NEE invests in gas and oil producing and transmission assets through NEER’s gas infrastructure business. The gas infrastructure business is exposed to fluctuating market prices of natural gas, natural gas liquids, oil and other energy commodities. A prolonged period of low gas and oil prices could impact NEER’s gas infrastructure business and cause NEER to delay or cancel certain gas infrastructure projects and could result in certain projects becoming impaired, which could materially adversely affect NEE's results of operations.

Natural gas and oil prices are affected by supply and demand, both globally and regionally. Factors that influence supply and demand include operational issues, natural disasters, weather, political instability, conflicts, new discoveries, technological advances, economic conditions and actions by major oil-producing countries. There can be significant volatility in market prices for gas and oil, and price fluctuations could have a material effect on the financial performance of gas and oil producing and transmission assets. For example, in a low gas and oil price environment, NEER would generate less revenue from its gas infrastructure investments in gas and oil producing properties, and as a result certain investments might become less profitable or incur losses. Prolonged periods of low oil and gas prices could also result in the delay or cancellation of oil and gas production and transmission projects, could cause projects to experience lower returns, and could result in certain projects becoming impaired, which could materially adversely affect NEE's results of operations.

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If supply costs necessary to provide NEER's full energy and capacity requirement services are not favorable, operating costs could increase and materially adversely affect NEE's business, financial condition, results of operations and prospects.

NEER provides full energy and capacity requirements services primarily to distribution utilities, which include load-following services and various ancillary services, to satisfy all or a portion of such utilities' power supply obligations to their customers. The supply costs for these transactions may be affected by a number of factors, including, but not limited to, events that may occur after such utilities have committed to supply power, such as weather conditions, fluctuating prices for energy and ancillary services, and the ability of the distribution utilities' customers to elect to receive service from competing suppliers. NEER may not be able to recover all of its increased supply costs, which could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.

Due to the potential for significant volatility in market prices for fuel, electricity and renewable and other energy commodities, NEER's inability or failure to manage properly or hedge effectively the commodity risks within its portfolios could materially adversely affect NEE's business, financial condition, results of operations and prospects.

There can be significant volatility in market prices for fuel, electricity and renewable and other energy commodities. NEE's inability or failure to manage properly or hedge effectively its assets or positions against changes in commodity prices, volumes, interest rates, counterparty credit risk or other risk measures, based on factors that are either within, or wholly or partially outside of, NEE's control, may materially adversely affect NEE's business, financial condition, results of operations and prospects.

Reductions in the liquidity of energy markets may restrict the ability of NEE to manage its operational risks, which, in turn, could negatively affect NEE's results of operations.

NEE is an active participant in energy markets. The liquidity of regional energy markets is an important factor in NEE's ability to manage risks in these operations. Market liquidity is driven in part by the number of active market participants. Liquidity in the energy markets can be adversely affected by price volatility, restrictions on the availability of credit and other factors, and any reduction in the liquidity of energy markets could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.

NEE's and FPL's hedging and trading procedures and associated risk management tools may not protect against significant losses.

NEE and FPL have hedging and trading procedures and associated risk management tools, such as separate but complementary financial, credit, operational, compliance and legal reporting systems, internal controls, management review processes and other mechanisms. NEE and FPL are unable to assure that such procedures and tools will be effective against all potential risks, including, without limitation, employee misconduct or severe weather or operating conditions. If such procedures and tools are not effective, this could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.

If price movements significantly or persistently deviate from historical behavior, NEE's and FPL's risk management tools associated with their hedging and trading procedures may not protect against significant losses.

NEE's and FPL's risk management tools and metrics associated with their hedging and trading procedures, such as daily value at risk, earnings at risk, stop loss limits and liquidity guidelines, are based on historical price movements. Due to the inherent uncertainty involved in price movements and potential deviation from historical pricing behavior, NEE and FPL are unable to assure that their risk management tools and metrics will be effective to protect against material adverse effects on their business, financial condition, results of operations and prospects.

If power transmission or natural gas, nuclear fuel or other commodity transportation facilities are unavailable or disrupted, the ability for subsidiaries of NEE, including FPL, to sell and deliver power or natural gas may be limited.

Subsidiaries of NEE, including FPL, depend upon power transmission and natural gas, nuclear fuel and other commodity transportation facilities, many of which they do not own. Occurrences affecting the operation of these facilities that may or may not be beyond the control of subsidiaries of NEE, including FPL, (such as severe weather or a generation or transmission facility outage, pipeline rupture, or sudden and significant increase or decrease in wind or solar generation) may limit or halt their ability to sell and deliver power and natural gas, or to purchase necessary fuels and other commodities, which could materially adversely impact NEE's and FPL's business, financial condition, results of operations and prospects.

NEE and FPL are subject to credit and performance risk from customers, hedging counterparties and vendors.

NEE and FPL are exposed to risks associated with the creditworthiness and performance of their customers, hedging counterparties and vendors under contracts for the supply of equipment, materials, fuel and other goods and services required for their business operations and for the construction and operation of, and for capital improvements to, their facilities. Adverse conditions in the energy industry or the general economy, as well as circumstances of individual customers, hedging

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counterparties and vendors, may adversely affect the ability of some customers, hedging counterparties and vendors to perform as required under their contracts with NEE and FPL.

If any hedging, vending or other counterparty fails to fulfill its contractual obligations, NEE and FPL may need to make arrangements with other counterparties or vendors, which could result in material financial losses, higher costs, untimely completion of power generation facilities and other projects, and/or a disruption of their operations. If a defaulting counterparty is in poor financial condition, NEE and FPL may not be able to recover damages for any contract breach.

NEE and FPL could recognize financial losses or a reduction in operating cash flows if a counterparty fails to perform or make payments in accordance with the terms of derivative contracts or if NEE or FPL is required to post margin cash collateral under derivative contracts.

NEE and FPL use derivative instruments, such as swaps, options, futures and forwards, some of which are traded in the OTC markets or on exchanges, to manage their commodity and financial market risks, and for NEE to engage in trading and marketing activities. Any failures by their counterparties to perform or make payments in accordance with the terms of those transactions could have a material adverse effect on NEE's or FPL's business, financial condition, results of operations and prospects. Similarly, any requirement for FPL or NEE to post margin cash collateral under its derivative contracts could have a material adverse effect on its business, financial condition, results of operations and prospects. These risks may be increased during periods of adverse market or economic conditions affecting the industry in which NEE and FPL participate.

NEE and FPL are highly dependent on sensitive and complex information technology systems, and any failure or breach of those systems could have a material adverse effect on their business, financial condition, results of operations and prospects.

NEE and FPL operate in a highly regulated industry that requires the continuous functioning of sophisticated information technology systems and network infrastructure. Despite NEE's and FPL's implementation of security measures, all of their technology systems are vulnerable to disability, failures or unauthorized access due to such activities. If NEE's or FPL's information technology systems were to fail or be breached, sensitive confidential and other data could be compromised and NEE and FPL could be unable to fulfill critical business functions.

NEE's and FPL's business is highly dependent on their ability to process and monitor, on a daily basis, a very large number of transactions, many of which are highly complex and cross numerous and diverse markets. Due to the size, scope, complexity and geographical reach of NEE's and FPL's business, the development and maintenance of information technology systems to keep track of and process information is critical and challenging. NEE's and FPL's operating systems and facilities may fail to operate properly or become disabled as a result of events that are either within, or wholly or partially outside of, their control, such as operator error, severe weather, terrorist activities or cyber incidents. Any such failure or disabling event could materially adversely affect NEE's and FPL's ability to process transactions and provide services, and their business, financial condition, results of operations and prospects.

NEE and FPL add, modify and replace information systems on a regular basis. Modifying existing information systems or implementing new or replacement information systems is costly and involves risks, including, but not limited to, integrating the modified, new or replacement system with existing systems and processes, implementing associated changes in accounting procedures and controls, and ensuring that data conversion is accurate and consistent. Any disruptions or deficiencies in existing information systems, or disruptions, delays or deficiencies in the modification or implementation of new information systems, could result in increased costs, the inability to track or collect revenues and the diversion of management's and employees' attention and resources, and could negatively impact the effectiveness of the companies' control environment, and/or the companies' ability to timely file required regulatory reports.

NEE and FPL also face the risks of operational failure or capacity constraints of third parties, including, but not limited to, those who provide power transmission and natural gas transportation services.

NEE's and FPL's retail businesses are subject to the risk that sensitive customer data may be compromised, which could result in a material adverse impact to their reputation and/or have a material adverse effect on the business, financial condition, results of operations and prospects of NEE and FPL.

NEE's and FPL's retail businesses require access to sensitive customer data in the ordinary course of business. NEE's and FPL's retail businesses may also need to provide sensitive customer data to vendors and service providers who require access to this information in order to provide services, such as call center services, to the retail businesses. If a significant breach occurred, the reputation of NEE and FPL could be materially adversely affected, customer confidence could be diminished, or customer information could be subject to identity theft. NEE and FPL would be subject to costs associated with the breach and/or NEE and FPL could be subject to fines and legal claims, any of which may have a material adverse effect on the business, financial condition, results of operations and prospects of NEE and FPL.

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NEE and FPL could recognize financial losses as a result of volatility in the market values of derivative instruments and limited liquidity in OTC markets.

NEE and FPL execute transactions in derivative instruments on either recognized exchanges or via the OTC markets, depending on management's assessment of the most favorable credit and market execution factors. Transactions executed in OTC markets have the potential for greater volatility and less liquidity than transactions on recognized exchanges. As a result, NEE and FPL may not be able to execute desired OTC transactions due to such heightened volatility and limited liquidity.

In the absence of actively quoted market prices and pricing information from external sources, the valuation of derivative instruments involves management's judgment and use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these derivative instruments and have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

NEE and FPL may be materially adversely affected by negative publicity.

From time to time, political and public sentiment may result in a significant amount of adverse press coverage and other adverse public statements affecting NEE and FPL. Adverse press coverage and other adverse statements, whether or not driven by political or public sentiment, may also result in investigations by regulators, legislators and law enforcement officials or in legal claims. Responding to these investigations and lawsuits, regardless of the ultimate outcome of the proceeding, can divert the time and effort of senior management from NEE's and FPL's business.

Addressing any adverse publicity, governmental scrutiny or enforcement or other legal proceedings is time consuming and expensive and, regardless of the factual basis for the assertions being made, can have a negative impact on the reputation of NEE and FPL, on the morale and performance of their employees and on their relationships with regulators. It may also have a negative impact on their ability to take timely advantage of various business and market opportunities. The direct and indirect effects of negative publicity, and the demands of responding to and addressing it, may have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

NEE's and FPL's business, financial condition, results of operations and prospects may be adversely affected if FPL is unable to maintain, negotiate or renegotiate franchise agreements on acceptable terms with municipalities and counties in Florida.

FPL may negotiate franchise agreements with municipalities and counties in Florida to provide electric services within such municipalities and counties, and electricity sales generated pursuant to these agreements represent a very substantial portion of FPL's revenues. If FPL is unable to maintain, negotiate or renegotiate such franchise agreements on acceptable terms, it could contribute to lower earnings and FPL may not fully realize the anticipated benefits from significant investments and expenditures, which could adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.

NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected by work strikes or stoppages and increasing personnel costs.

Employee strikes or work stoppages could disrupt operations and lead to a loss of revenue and customers. Personnel costs may also increase due to inflationary or competitive pressures on payroll and benefits costs and revised terms of collective bargaining agreements with union employees. These consequences could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

NEE's ability to successfully identify, complete and integrate acquisitions is subject to significant risks, including, but not limited to, the effect of increased competition for acquisitions resulting from the consolidation of the energy industry.

NEE is likely to encounter significant competition for acquisition opportunities that may become available as a result of the consolidation of the energy industry in general. In addition, NEE may be unable to identify attractive acquisition opportunities at favorable prices and to complete and integrate them successfully and in a timely manner.

Nuclear Generation Risks

The operation and maintenance of NEE's and FPL's nuclear generation facilities involve environmental, health and financial risks that could result in fines or the closure of the facilities and in increased costs and capital expenditures.

NEE's and FPL's nuclear generation facilities are subject to environmental, health and financial risks, including, but not limited to, those relating to site storage of spent nuclear fuel, the disposition of spent nuclear fuel, leakage and emissions of tritium and other radioactive elements in the event of a nuclear accident or otherwise, the threat of a terrorist attack or cyber incident and other potential liabilities arising out of the ownership or operation of the facilities. NEE and FPL maintain decommissioning funds and external insurance coverage which are intended to reduce the financial exposure to some of these risks; however, the cost of decommissioning nuclear generation facilities could exceed the amount available in NEE's and FPL's decommissioning funds,

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and the exposure to liability and property damages could exceed the amount of insurance coverage. If NEE or FPL is unable to recover the additional costs incurred through insurance or, in the case of FPL, through regulatory mechanisms, their business, financial condition, results of operations and prospects could be materially adversely affected.

In the event of an incident at any nuclear generation facility in the U.S. or at certain nuclear generation facilities in Europe, NEE and FPL could be assessed significant retrospective assessments and/or retrospective insurance premiums as a result of their participation in a secondary financial protection system and nuclear insurance mutual companies.

Liability for accidents at nuclear power plants is governed by the Price-Anderson Act, which limits the liability of nuclear reactor owners to the amount of insurance available from both private sources and an industry retrospective payment plan. In accordance with this Act, NEE maintains the maximum amount of private liability insurance obtainable, and participates in a secondary financial protection system, which provides liability insurance coverage for an incident at any nuclear reactor in the U.S. Under the secondary financial protection system, NEE is subject to retrospective assessments and/or retrospective insurance premiums, plus any applicable taxes, for an incident at any nuclear reactor in the U.S. or at certain nuclear generation facilities in Europe, regardless of fault or proximity to the incident. Such assessments, if levied, could materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.

NRC orders or new regulations related to increased security measures and any future safety requirements promulgated by the NRC could require NEE and FPL to incur substantial operating and capital expenditures at their nuclear generation facilities and/or result in reduced revenues.

The NRC has broad authority to impose licensing and safety-related requirements for the operation and maintenance of nuclear generation facilities, the addition of capacity at existing nuclear generation facilities and the construction of new nuclear generation facilities, and these requirements are subject to change. In the event of non-compliance, the NRC has the authority to impose fines and/or shut down a nuclear generation facility, depending upon the NRC's assessment of the severity of the situation, until compliance is achieved. Any of the foregoing events could require NEE and FPL to incur increased costs and capital expenditures, and could reduce revenues.

Any serious nuclear incident occurring at a NEE or FPL plant could result in substantial remediation costs and other expenses. A major incident at a nuclear facility anywhere in the world could cause the NRC to limit or prohibit the operation or licensing of any domestic nuclear generation facility. An incident at a nuclear facility anywhere in the world also could cause the NRC to impose additional conditions or other requirements on the industry, or on certain types of nuclear generation units, which could increase costs, reduce revenues and result in additional capital expenditures.

The inability to operate any of NEE's or FPL's nuclear generation units through the end of their respective operating licenses could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

If any of NEE's or FPL's nuclear generation facilities are not operated for any reason through the life of their respective operating licenses, NEE or FPL may be required to increase depreciation rates, incur impairment charges and accelerate future decommissioning expenditures, any of which could materially adversely affect their business, financial condition, results of operations and prospects.

NEE's and FPL's nuclear units are periodically removed from service to accommodate planned refueling and maintenance outages, and for other purposes. If planned outages last longer than anticipated or if there are unplanned outages, NEE's and FPL's results of operations and financial condition could be materially adversely affected.

NEE's and FPL's nuclear units are periodically removed from service to accommodate planned refueling and maintenance outages, including, but not limited to, inspections, repairs and certain other modifications as well as to replace equipment. In the event that a scheduled outage lasts longer than anticipated or in the event of an unplanned outage due to, for example, equipment failure, such outages could materially adversely affect NEE's or FPL's business, financial condition, results of operations and prospects.

Liquidity, Capital Requirements and Common Stock Risks

Disruptions, uncertainty or volatility in the credit and capital markets, among other factors, may negatively affect NEE's and FPL's ability to fund their liquidity and capital needs and to meet their growth objectives, and can also materially adversely affect the results of operations and financial condition of NEE and FPL.

NEE and FPL rely on access to capital and credit markets as significant sources of liquidity for capital requirements and other operations requirements that are not satisfied by operating cash flows. Disruptions, uncertainty or volatility in those capital and credit markets, including, but not limited to, the planned phase out of the London Inter-Bank Offered Rate or the reform or replacement of other benchmark rates, could increase NEE's and FPL's cost of capital and affect their ability to fund their liquidity and capital needs and to meet their growth objectives. If NEE or FPL is unable to access regularly the capital and credit markets on terms that are reasonable, it may have to delay raising capital, issue shorter-term securities and incur an unfavorable cost of

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capital, which, in turn, could adversely affect its ability to grow its business, could contribute to lower earnings and reduced financial flexibility, and could have a material adverse effect on its business, financial condition, results of operations and prospects.

Although NEE's competitive energy and certain other subsidiaries have used non-recourse or limited-recourse, project-specific or other financing in the past, market conditions and other factors could adversely affect the future availability of such financing. The inability of NEE's subsidiaries, including, without limitation, NEECH and its subsidiaries, to access the capital and credit markets to provide project-specific or other financing for electric generation or other facilities or acquisitions on favorable terms, whether because of disruptions or volatility in those markets or otherwise, could necessitate additional capital raising or borrowings by NEE and/or NEECH in the future.

The inability of subsidiaries that have existing project-specific or other financing arrangements to meet the requirements of various agreements relating to those financings, as well as actions by third parties or lenders, could give rise to a project-specific financing default which, if not cured or waived, might result in the specific project, and potentially in some limited instances its parent companies, being required to repay the associated debt or other borrowings earlier than otherwise anticipated, and if such repayment were not made, the lenders or security holders would generally have rights to foreclose against the project assets and related collateral. Such an occurrence also could result in NEE expending additional funds or incurring additional obligations over the shorter term to ensure continuing compliance with project-specific financing arrangements based upon the expectation of improvement in the project's performance or financial returns over the longer term. Any of these actions could materially adversely affect NEE's business, financial condition, results of operations and prospects, as well as the availability or terms of future financings for NEE or its subsidiaries.

NEE's, NEECH's and FPL's inability to maintain their current credit ratings may materially adversely affect NEE's and FPL's liquidity and results of operations, limit the ability of NEE and FPL to grow their business, and increase interest costs.

The inability of NEE, NEECH and FPL to maintain their current credit ratings could materially adversely affect their ability to raise capital or obtain credit on favorable terms, which, in turn, could impact NEE's and FPL's ability to grow their business and service indebtedness and repay borrowings, and would likely increase their interest costs. In addition, certain agreements and guarantee arrangements would require posting of additional collateral in the event of a ratings downgrade. Some of the factors that can affect credit ratings are cash flows, liquidity, the amount of debt as a component of total capitalization, NEE's overall business mix and political, legislative and regulatory actions. There can be no assurance that one or more of the ratings of NEE, NEECH and FPL will not be lowered or withdrawn entirely by a rating agency.

NEE's and FPL's liquidity may be impaired if their credit providers are unable to fund their credit commitments to the companies or to maintain their current credit ratings.

The inability of NEE's, NEECH's and FPL's credit providers to fund their credit commitments or to maintain their current credit ratings could require NEE, NEECH or FPL, among other things, to renegotiate requirements in agreements, find an alternative credit provider with acceptable credit ratings to meet funding requirements, or post cash collateral and could have a material adverse effect on NEE's and FPL's liquidity.

Poor market performance and other economic factors could affect NEE's defined benefit pension plan's funded status, which may materially adversely affect NEE's and FPL's business, financial condition, liquidity and results of operations and prospects.

NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries. A decline in the market value of the assets held in the defined benefit pension plan due to poor investment performance or other factors may increase the funding requirements for this obligation.

NEE's defined benefit pension plan is sensitive to changes in interest rates, since as interest rates decrease, the funding liabilities increase, potentially increasing benefits costs and funding requirements. Any increase in benefits costs or funding requirements may have a material adverse effect on NEE's and FPL's business, financial condition, liquidity, results of operations and prospects.

Poor market performance and other economic factors could adversely affect the asset values of NEE's and FPL's nuclear decommissioning funds, which may materially adversely affect NEE's and FPL's liquidity, financial condition and results of operations.

NEE and FPL are required to maintain decommissioning funds to satisfy their future obligations to decommission their nuclear power plants. A decline in the market value of the assets held in the decommissioning funds due to poor investment performance or other factors may increase the funding requirements for these obligations. Any increase in funding requirements may have a material adverse effect on NEE's and FPL's liquidity, financial condition and results of operations.

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Certain of NEE's investments are subject to changes in market value and other risks, which may materially adversely affect NEE's liquidity, financial condition and results of operations.

NEE holds certain investments where changes in the fair value affect NEE's financial results. In some cases there may be no observable market values for these investments, requiring fair value estimates to be based on other valuation techniques. This type of analysis requires significant judgment and the actual values realized in a sale of these investments could differ materially from those estimated. A sale of an investment below previously estimated value, or other decline in the fair value of an investment, could result in losses or the write-off of such investment, and may have a material adverse effect on NEE's liquidity, financial condition and results of operations.

NEE may be unable to meet its ongoing and future financial obligations and to pay dividends on its common stock if its subsidiaries are unable to pay upstream dividends or repay funds to NEE.

NEE is a holding company and, as such, has no material operations of its own. Substantially all of NEE's consolidated assets are held by its subsidiaries. NEE's ability to meet its financial obligations, including, but not limited to, its guarantees, and to pay dividends on its common stock is primarily dependent on its subsidiaries' net income and cash flows, which are subject to the risks of their respective businesses, and their ability to pay upstream dividends or to repay funds to NEE.

NEE's subsidiaries are separate legal entities and have no independent obligation to provide NEE with funds for its payment obligations. The subsidiaries have financial obligations, including, but not limited to, payment of debt service, which they must satisfy before they can provide NEE with funds. In addition, in the event of a subsidiary's liquidation or reorganization, NEE's right to participate in a distribution of assets is subject to the prior claims of the subsidiary's creditors.

The dividend-paying ability of some of the subsidiaries is limited by contractual restrictions which are contained in outstanding financing agreements and which may be included in future financing agreements. The future enactment of laws or regulations also may prohibit or restrict the ability of NEE's subsidiaries to pay upstream dividends or to repay funds.

NEE may be unable to meet its ongoing and future financial obligations and to pay dividends on its common stock if NEE is required to perform under guarantees of obligations of its subsidiaries.

NEE guarantees many of the obligations of its consolidated subsidiaries, other than FPL, through guarantee agreements with NEECH. These guarantees may require NEE to provide substantial funds to its subsidiaries or their creditors or counterparties at a time when NEE is in need of liquidity to meet its own financial obligations. Funding such guarantees may materially adversely affect NEE's ability to meet its financial obligations or to pay dividends.

NEP may not be able to access sources of capital on commercially reasonable terms, which would have a material adverse effect on its ability to consummate future acquisitions and on the value of NEE’s limited partner interest in NEP OpCo.

Through an indirect wholly owned subsidiary, NEE owns a limited partner interest in NEP OpCo. NEP's inability to access capital on commercially reasonable terms and effectively consummate future acquisitions could have a material adverse effect on NEP's ability to grow its cash distributions to its common unitholders, including NEE, and on the value of NEE’s limited partnership interest in NEP OpCo. In addition, NEP's issuance of additional common units, securities convertible into NEP common units or other securities in connection with acquisitions could cause significant common unitholder dilution and reduce cash distributions to its common unitholders, including NEE, if the acquisitions are not sufficiently accretive.

Disruptions, uncertainty or volatility in the credit and capital markets may exert downward pressure on the market price of NEE's common stock.

The market price and trading volume of NEE's common stock are subject to fluctuations as a result of, among other factors, general credit and capital market conditions and changes in market sentiment regarding the operations, business and financing strategies of NEE and its subsidiaries. As a result, disruptions, uncertainty or volatility in the credit and capital markets may, for example, have a material adverse effect on the market price of NEE's common stock.

Widespread public health crises and epidemics or pandemics may have material adverse impacts on NEE’s and FPL's business, financial condition, liquidity and results of operations.

NEE and FPL are subject to the impacts of widespread public health crises, epidemics and pandemics, including, but not limited to, impacts on the global, national or local economy, capital and credit markets, NEE's and FPL's workforce, customers and suppliers. There is no assurance that NEE's and FPL's businesses will be able to operate without material adverse impacts depending on the nature of the public health crisis, epidemic or pandemic. The ultimate severity, duration and impact of public health crises, epidemics and pandemics cannot be predicted. Additionally, there is no assurance that vaccines, or other treatments, are or will be widely available or effective, or that the public will be willing to participate, in an effort to contain the spread of disease. Actions taken in response to such crises by federal, state and local government or regulatory agencies may have a material adverse impact on NEE's and FPL's business, financial condition, liquidity and results of operations.

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Item 1B. Unresolved Staff Comments

None

Item 2. Properties

See Item 1. Business – FPL and Item 1. Business – NEER for a description of principal properties.

Character of Ownership

Substantially all of FPL's properties are subject to the lien of FPL's mortgage, which secures most debt securities issued by FPL. The majority of FPL's real property is held in fee and is free from other encumbrances, subject to minor exceptions which are not of a nature as to substantially impair the usefulness to FPL of such properties. Some of FPL's electric lines are located on parcels of land which are not owned in fee by FPL but are covered by necessary consents of governmental authorities or rights obtained from owners of private property. Subsidiaries within the NEER segment have ownership interests in entities that own generation facilities, pipeline facilities and transmission assets and a number of those facilities and assets are encumbered by liens securing various financings. Additionally, the majority of NEER's generation facilities, pipeline facilities and transmission lines are located on land under easement or leased from owners of private property. See Note 7 – FPL and – NEER.

Item 3. Legal Proceedings

With regard to environmental proceedings to which a governmental authority is a party, NEE's and FPL's policy is to disclose any such proceeding if it is reasonably expected to result in monetary sanctions of greater than or equal to $1 million.

The Environment and Natural Resources Division of the U.S. Department of Justice (DOJ) indicated to NEER during the fourth quarter of 2021 that its final position is that the act of an eagle flying into a wind turbine that results in the death of the eagle is a crime under the Migratory Bird Treaty Act (MBTA) and Bald and Golden Eagle Protection Act (BGEPA). The DOJ is investigating eagle fatalities that have occurred in proximity to a number of wind facilities operated by NEER, primarily in the Altamont region of California and in Wyoming, and alleges that the facilities caused eagle fatalities without having a permit in violation of the BGEPA and/or the MBTA. NEER undertakes adaptive management practices designed to avoid and minimize eagle impacts and is working with both the DOJ and the U.S. Fish and Wildlife Service toward a constructive resolution that would resolve all prior fatalities at wind facilities operated by NEER nationwide, even though federal courts covering large portions of the U.S. have concluded that these statutes are intended to cover only hunting, poaching and other intentional acts and do not apply to accidental collisions with wind turbines or other structures, such as airplanes and buildings. NEE anticipates that any such resolution would not have a material adverse impact on its business, financial condition, results of operations or prospects.

Item 4. Mine Safety Disclosures

Not applicable

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PART II

Item 5.  Market for Registrants' Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Common Stock Data. All of FPL's common stock is owned by NEE. NEE's common stock is traded on the New York Stock Exchange under the symbol "NEE." As of January 31, 2022, there were 15,274 holders of record of NEE's common stock. The amount and timing of dividends payable on NEE's common stock are within the sole discretion of NEE's Board of Directors. The Board of Directors reviews the dividend rate at least annually (generally in February) to determine its appropriateness in light of NEE's financial position and results of operations, legislative and regulatory developments affecting the electric utility industry in general and FPL in particular, competitive conditions, change in business mix and any other factors the Board of Directors deems relevant. In February 2022, NEE announced that it would increase its quarterly dividend on its common stock from $0.385 per share to $0.425 per share.

Issuer Purchases of Equity Securities. Information regarding purchases made by NEE of its common stock during the three months ended December 31, 2021 is as follows:

Period	Total Number of Shares Purchased(a)	Average Price Paid Per Share		Total Number of Shares Purchased as Part of a Publicly Announced Program	Maximum Number of Shares that May Yet be Purchased Under the Program(b)
10/1/21 – 10/31/21	—	—		—	180,000,000
11/1/21 – 11/30/21	1,350	$	87.34	—	180,000,000
12/1/21 – 12/31/21	1,306	$	90.78	—	180,000,000
Total	2,656	$	89.03	—

______________________

(a)Includes: (1) in November 2021, shares of common stock withheld from employees to pay certain withholding taxes upon the vesting of stock awards granted to such employees under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan; and (2) in December 2021, shares of common stock purchased as a reinvestment of dividends by the trustee of a grantor trust in connection with NEE's obligation under a February 2006 grant under the NextEra Energy, Inc. Amended and Restated Long-Term Incentive Plan (former LTIP) to an executive officer of deferred retirement share awards.

(b)In May 2017, NEE's Board of Directors authorized repurchases of up to 45 million shares of common stock (180 million shares after giving effect to the four-for-one stock split of NEE common stock effective October 26, 2020) over an unspecified period.

Item 6.  Reserved

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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.

	Net Income (Loss) Attributable to NEE						Earnings (Loss) Per Share Attributable to NEE, Assuming Dilution
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
	(millions)
FPL Segment	$	2,935	$	2,650	$	2,334	$	1.49	$	1.35	$	1.20
Gulf Power	271		238		180		0.14		0.12		0.09
NEER(a)	599		531		1,807		0.30		0.27		0.93
Corporate and Other	(232)		(500)		(552)		(0.12)		(0.26)		(0.28)
NEE	$	3,573	$	2,919	$	3,769	$	1.81	$	1.48	$	1.94

______________________

(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.

	Years Ended December 31,
	2021		2020		2019
			(millions)
Net losses associated with non-qualifying hedge activity(a)	$	(1,576)	$	(649)	$	(406)
Differential membership interests-related – NEER	$	(98)	$	(87)	$	(89)
NEP investment gains, net – NEER	$	27	$	(94)	$	96
Gain on disposal of a business – NEER(b)	$	—	$	274	$	—
Change in unrealized gains (losses) on NEER's nuclear decommissioning funds and OTTI, net – NEER	$	199	$	131	$	176
Acquisition-related(c)	$	—	$	—	$	(70)
Impairment charge related to investment in Mountain Valley Pipeline – NEER(d)	$	—	$	(1,208)	$	—

______________________

(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.

	Net Income
	Years Ended December 31,
	2021		2020		2019
	(millions)
FPL Segment	$	2,935	$	2,650	$	2,334
Gulf Power	271		238		180
Corporate and Other	—		2		5
FPL	$	3,206	$	2,890	$	2,519

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:

	Years Ended December 31,
	2021		2020
	(millions)
Reserve reversal (amortization) recorded under the 2016 rate agreement	$	(429)	$	1
Other depreciation and amortization recovered under base rates (excluding reserve amortization) and other	2,168		2,017
Depreciation and amortization primarily recovered under cost recovery clauses and securitized storm-recovery cost amortization	229		228
Total	$	1,968	$	2,246

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.

	Increase (Decrease) From Prior Period
	Year Ended December 31, 2021
	(millions)
New investments(a)	$	235
Existing generation and storage assets(a)	(70)
Gas infrastructure(a)	49
Customer supply and proprietary power and gas trading(b)	(37)
NEET(b)	13
Other, including income taxes and other investment income	52
Change in non-qualifying hedge activity(c)	(1,297)
Change in unrealized gains/losses on equity securities held in nuclear decommissioning funds and OTTI, net(c)	68
NEP investment gains, net(c)	121
Disposal of a business(c)	(274)
Impairment charge related to investment in Mountain Valley Pipeline(c)	1,208
Increase in net income less net loss attributable to noncontrolling interests	$	68

______________________

(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:

	Years Ended December 31,
	2021		2020		2019
	(millions)
Sources of cash:
Cash flows from operating activities	$	7,553	$	7,983	$	8,155
Issuances of long-term debt, including premiums and discounts	16,683		12,404		13,905
Proceeds from differential membership investors	2,779		3,522		1,604
Sale of independent power and other investments of NEER	2,761		1,012		1,316
Issuances of common stock/equity units – net	14		—		1,494
Payments from related parties under a cash sweep and credit support agreement – net	47		—		—
Proceeds from sale of noncontrolling interests	65		501		99
Other sources – net	40		83		121
Total sources of cash	29,942		25,505		26,694
Uses of cash:
Capital expenditures, acquisitions, independent power and other investments and nuclear fuel purchases	(16,077)		(14,610)		(17,462)
Retirements of long-term debt	(9,594)		(6,103)		(5,492)
Net decrease in commercial paper and other short-term debt(a)	(426)		(907)		(4,799)
Payments to related parties under a cash sweep and credit support agreement – net	—		(2)		(54)
Issuances of common stock/equity units – net	—		(92)		—
Dividends	(3,024)		(2,743)		(2,408)
Other uses – net	(1,052)		(590)		(628)
Total uses of cash	(30,173)		(25,047)		(30,843)
Effects of currency translation on cash, cash equivalents and restricted cash	1		(20)		4
Net increase (decrease) in cash, cash equivalents and restricted cash	$	(230)	$	438	$	(4,145)

______________________

(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.

	Years Ended December 31,
	2021		2020		2019
	(millions)
FPL Segment:
Generation:
New	$	830	$	1,464	$	1,242
Existing	1,380		1,063		1,215
Transmission and distribution	4,065		3,150		2,893
Nuclear fuel	159		203		195
General and other	835		651		550
Other, primarily change in accrued property additions and exclusion of AFUDC – equity	(484)		149		(340)
Total	6,785		6,680		5,755
Gulf Power	782		1,012		729
NEER:
Wind	3,777		3,359		1,974
Solar (includes solar plus battery storage projects)	2,011		1,920		1,741
Battery storage	304		168		29
Nuclear, including nuclear fuel	241		125		179
Natural gas pipelines	229		269		687
Other gas infrastructure	669		572		969
Rate-regulated transmission (2021 and 2019 includes acquisitions, see Note 6)	980		360		829
Other	152		120		97
Total	8,363		6,893		6,505
Corporate and Other (2019 primarily relates to acquisitions, see Note 6)	147		25		4,473
Total capital expenditures, independent power and other investments and nuclear fuel purchases	$	16,077	$	14,610	$	17,462

.

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.

							Maturity Date
	FPL		NEECH		Total		FPL	NEECH
	(millions)
Syndicated revolving credit facilities(a)	$	3,798	$	5,257	$	9,055	2022 – 2026	2022 – 2026
Issued letters of credit	(3)		(1,374)		(1,377)
	3,795		3,883		7,678
Bilateral revolving credit facilities(b)	780		2,675		3,455		2022 – 2024	2022 – 2023
Borrowings	—		—		—
	780		2,675		3,455
Letter of credit facilities(c)	—		2,300		2,300			2022 – 2024
Issued letters of credit	—		(1,307)		(1,307)
	—		993		993
Subtotal	4,575		7,551		12,126
Cash and cash equivalents	55		582		637
Commercial paper and other short-term borrowings outstanding	(1,582)		(500)		(2,082)
Amounts due to related parties under the CSCS agreement (see Note 8)	—		(57)		(57)
Net available liquidity	$	3,048	$	7,576	$	10,624

______________________

(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:

	Year Ended December 31, 2021
	Issuer/Guarantor Combined(a)		NEECH Consolidated(b)		NEE Consolidated(b)
	(millions)
Operating revenues	$	(1)	$	3,139	$	17,069
Operating income (loss)	$	(352)	$	(1,317)	$	2,913
Net income (loss)	$	(275)	$	(395)	$	2,827
Net income (loss) attributable to NEE/NEECH	$	(275)	$	351	$	3,573

	December 31, 2021
	Issuer/Guarantor Combined(a)		NEECH Consolidated(b)		NEE Consolidated(b)
	(millions)
Total current assets	$	48	$	5,662	$	9,288
Total noncurrent assets	$	2,308	$	57,620	$	131,624
Total current liabilities	$	1,553	$	11,560	$	17,437
Total noncurrent liabilities	$	27,956	$	40,289	$	77,806
Redeemable noncontrolling interests	$	—	$	245	$	245
Noncontrolling interests	$	—	$	8,222	$	8,222

————————————
(a)	Excludes intercompany transactions, and investments in, and equity in earnings of, subsidiaries.
(b)	Information has been prepared on the same basis of accounting as NEE's consolidated financial statements.

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:

	Moody's(a)	S&P(a)	Fitch(a)
NEE:(b)
Corporate credit rating	Baa1	A-	A-
FPL:(b)
Corporate credit rating	A1	A	A
First mortgage bonds	Aa2	A+	AA-
Senior unsecured notes	A1	A	A+
Pollution control, solid waste disposal and industrial development revenue bonds(c)	VMIG-1/P-1	A-1	F1
Commercial paper	P-1	A-1	F1
NEECH:(b)
Corporate credit rating	Baa1	A-	A-
Debentures	Baa1	BBB+	A-
Junior subordinated debentures	Baa2	BBB	BBB
Commercial paper	P-2	A-2	F2

_________________________

(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:

	2021		2020		2019
Discount rate	2.53	%	3.22	%	4.26	%
Salary increase	4.40	%	4.40	%	4.40	%
Expected long-term rate of return, net of investment management fees	7.35	%	7.35	%	7.35	%
Weighted-average interest crediting rate	3.82	%	3.83	%	3.88	%

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:

		Increase (Decrease) in 2021 Net Periodic Pension Income
	Change in Assumption	NEE		FPL
		(millions)
Expected long-term rate of return	(0.5)%	$	(24)	$	(16)
Discount rate	0.5%	$	13	$	9
Salary increase	0.5%	$	(4)	$	(3)

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:

	Nuclear Decommissioning				Other Generation Plant Dismantlement				Interim Removal Costs and Other				Total
	December 31,				December 31,				December 31,				December 31,
	2021		2020		2021		2020		2021		2020		2021		2020
	(millions)
AROs(a)	$	1,736	$	1,604	$	364	$	326	$	7	$	6	$	2,107	$	1,936
Less capitalized ARO asset net of accumulated depreciation	63		—		56		59		1		1		120		60
Accrued asset removal costs(b)	447		408		198		227		(156)		544		489		1,179
Asset retirement obligation regulatory expense difference(c)	4,399		3,690		(218)		(185)		(9)		(5)		4,172		3,500
Accrued decommissioning, dismantlement and other accrued asset removal costs(d)	$	6,519	$	5,702	$	288	$	309	$	(159)	$	544	$	6,648	$	6,555

______________________

(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:

			Hedges on Owned Assets
	Trading			Non- Qualifying		FPL Cost Recovery Clauses		NEE Total
	(millions)
Fair value of contracts outstanding at December 31, 2019	$	651		$	1,209	$	(11)	$	1,849
Reclassification to realized at settlement of contracts	(329)			(253)		12		(570)
Value of contracts acquired	91			(36)		—		55
Net option premium purchases (issuances)	10			4		—		14
Changes in fair value excluding reclassification to realized	283			72		(1)		354
Fair value of contracts outstanding at December 31, 2020	706			996		—		1,702
Reclassification to realized at settlement of contracts	179			293		(7)		465
Value of contracts acquired	80			9		—		89
Net option premium purchases (issuances)	23			11		—		34
Changes in fair value excluding reclassification to realized	(10)			(2,701)		8		(2,703)
Fair value of contracts outstanding at December 31, 2021	978			(1,392)		1		(413)
Net margin cash collateral paid (received)								(28)
Total mark-to-market energy contract net assets (liabilities) at December 31, 2021	$	978		$	(1,392)	$	1	$	(441)

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:

	December 31, 2021
	(millions)
Current derivative assets	$	689
Noncurrent derivative assets	1,068
Current derivative liabilities	(1,175)
Noncurrent derivative liabilities	(1,023)
NEE's total mark-to-market energy contract net liabilities	$	(441)

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

	Maturity
	2022		2023		2024		2025		2026		Thereafter		Total
	(millions)
Trading:
Quoted prices in active markets for identical assets	$	(190)	$	(176)	$	(145)	$	(95)	$	(7)	$	1	$	(612)
Significant other observable inputs	499		422		248		195		81		97		1,542
Significant unobservable inputs	(139)		(79)		1		22		30		213		48
Total	170		167		104		122		104		311		978
Owned Assets – Non-Qualifying:
Quoted prices in active markets for identical assets	(37)		(24)		(2)		—		—		—		(63)
Significant other observable inputs	(479)		(371)		(253)		(150)		(91)		(101)		(1,445)
Significant unobservable inputs	29		17		12		18		19		21		116
Total	(487)		(378)		(243)		(132)		(72)		(80)		(1,392)
Owned Assets – FPL Cost Recovery Clauses:
Quoted prices in active markets for identical assets	—		—		—		—		—		—		—
Significant other observable inputs	(5)		—		—		—		—		—		(5)
Significant unobservable inputs	7		(1)		—		—		—		—		6
Total	2		(1)		—		—		—		—		1
Total sources of fair value	$	(315)	$	(212)	$	(139)	$	(10)	$	32	$	231	$	(413)

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:

	Trading(a)						Non-Qualifying Hedges and Hedges in FPL Cost Recovery Clauses(b)						Total
	FPL		NEER		NEE		FPL		NEER		NEE		FPL		NEER		NEE
									(millions)
December 31, 2020	$	—	$	3	$	3	$	1	$	77	$	78	$	1	$	84	$	85
December 31, 2021	$	—	$	17	$	17	$	1	$	148	$	148	$	1	$	149	$	149
Average for the year ended December 31, 2021	$	—	$	11	$	11	$	—	$	100	$	100	$	—	$	101	$	101

______________________

(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:

	December 31, 2021				December 31, 2020
	Carrying Amount		Estimated Fair Value(a)		Carrying Amount		Estimated Fair Value(a)
	(millions)
NEE:
Fixed income securities:
Special use funds	$	2,505	$	2,505	$	2,134	$	2,134
Other investments, primarily debt securities	$	311	$	311	$	247	$	247
Long-term debt, including current portion	$	52,745	$	57,290	$	46,082	$	51,525
Interest rate contracts – net unrealized losses	$	(633)	$	(633)	$	(961)	$	(961)
FPL:
Fixed income securities – special use funds	$	1,934	$	1,934	$	1,617	$	1,617
Long-term debt, including current portion	$	18,510	$	21,379	$	17,236	$	21,178

______________________

(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.

Item 7A.  Quantitative and Qualitative Disclosures About Market Risk

See Management’s Discussion – Energy Marketing and Trading and Market Risk Sensitivity.

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Item 8.  Financial Statements and Supplementary Data

MANAGEMENT'S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

NextEra Energy, Inc.'s (NEE) and Florida Power & Light Company's (FPL) management are responsible for establishing and maintaining adequate internal control over financial reporting as defined in the Securities Exchange Act of 1934 Rules 13a-15(f) and 15d-15(f). The consolidated financial statements, which in part are based on informed judgments and estimates made by management, have been prepared in conformity with generally accepted accounting principles applied on a consistent basis.

To aid in carrying out this responsibility, we, along with all other members of management, maintain a system of internal accounting control which is established after weighing the cost of such controls against the benefits derived. In the opinion of management, the overall system of internal accounting control provides reasonable assurance that the assets of NEE and FPL and their subsidiaries are safeguarded and that transactions are executed in accordance with management's authorization and are properly recorded for the preparation of financial statements. In addition, management believes the overall system of internal accounting control provides reasonable assurance that material errors or irregularities would be prevented or detected on a timely basis by employees in the normal course of their duties. Any system of internal accounting control, no matter how well designed, has inherent limitations, including the possibility that controls can be circumvented or overridden and misstatements due to error or fraud may occur and not be detected. Also, because of changes in conditions, internal control effectiveness may vary over time. Accordingly, even an effective system of internal control will provide only reasonable assurance with respect to financial statement preparation and reporting.

The system of internal accounting control is supported by written policies and guidelines, the selection and training of qualified employees, an organizational structure that provides an appropriate division of responsibility and a program of internal auditing. NEE's written policies include a Code of Business Conduct & Ethics that states management's policy on conflicts of interest and ethical conduct. Compliance with the Code of Business Conduct & Ethics is confirmed annually by key personnel.

The Board of Directors pursues its oversight responsibility for financial reporting and accounting through its Audit Committee. This Committee, which is comprised entirely of independent directors, meets regularly with management, the internal auditors and the independent auditors to make inquiries as to the manner in which the responsibilities of each are being discharged. The independent auditors and the internal audit staff have free access to the Committee without management present to discuss auditing, internal accounting control and financial reporting matters.

Management assessed the effectiveness of NEE's and FPL's internal control over financial reporting as of December 31, 2021, using the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission in the Internal Control – Integrated Framework (2013). Based on this assessment, management believes that NEE's and FPL's internal control over financial reporting was effective as of December 31, 2021.

NEE's and FPL's independent registered public accounting firm, Deloitte & Touche LLP, is engaged to express an opinion on NEE's and FPL's consolidated financial statements and an opinion on NEE's and FPL's internal control over financial reporting. Their reports are based on procedures believed by them to provide a reasonable basis to support such opinions. These reports appear on the following pages.

JAMES L. ROBO	REBECCA J. KUJAWA
James L. Robo Chairman, President and Chief Executive Officer of NEE and Chairman of FPL	Rebecca J. Kujawa Executive Vice President, Finance and Chief Financial Officer of NEE and FPL

JAMES M. MAY

James M. May
Vice President, Controller and Chief Accounting Officer
of NEE

ERIC E. SILAGY	KEITH FERGUSON
Eric E. Silagy President and Chief Executive Officer of FPL	Keith Ferguson Controller of FPL

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the shareholders and the Board of Directors of

NextEra Energy, Inc. and Florida Power & Light Company

Opinion on Internal Control over Financial Reporting

We have audited the internal control over financial reporting of NextEra Energy, Inc. and subsidiaries (NEE) and Florida Power & Light Company and subsidiaries (FPL) as of December 31, 2021, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, NEE and FPL maintained, in all material respects, effective internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control – Integrated Framework (2013) issued by COSO.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated financial statements as of and for the year ended December 31, 2021 of NEE and FPL and our report dated February 17, 2022, expressed unqualified opinions on those financial statements.

Basis for Opinion

NEE's and FPL’s management are responsible for maintaining effective internal control over financial reporting and for their assessments of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express opinions on NEE’s and FPL’s internal control over financial reporting based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to NEE and FPL in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audits included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

Definition and Limitations of Internal Control over Financial Reporting

A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

DELOITTE & TOUCHE LLP

Boca Raton, Florida

February 17, 2022

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the shareholders and the Board of Directors of

    NextEra Energy, Inc. and Florida Power & Light Company

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of NextEra Energy, Inc. and subsidiaries (NEE) and the related separate consolidated balance sheets of Florida Power & Light Company and subsidiaries (FPL) as of December 31, 2021 and 2020, and NEE's and FPL's related consolidated statements of income and cash flows, NEE's consolidated statements of comprehensive income and equity, and FPL’s consolidated statements of common shareholder’s equity, for each of the three years in the period ended December 31, 2021, and the related notes (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the consolidated financial position of NEE and the consolidated financial position of FPL as of December 31, 2021 and 2020, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2021, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), NEE’s and FPL’s internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 17, 2022, expressed unqualified opinions on NEE’s and FPL’s internal control over financial reporting.

Emphasis of Matter

As discussed in Note 6 to the financial statements, on January 1, 2021, FPL and Gulf Power Company merged, with FPL as the surviving entity. FPL’s 2019 and 2020 financial statements have been retrospectively adjusted to reflect this merger. Our opinion is not modified with respect to this matter.

Basis for Opinion

These financial statements are the responsibility of NEE’s and FPL’s management. Our responsibility is to express opinions on NEE’s and FPL’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to NEE and FPL in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinions.

Critical Audit Matters

The critical audit matters communicated below are matters arising from the current-period audit of the financial statements of NEE and FPL that were communicated or required to be communicated to the audit committee and that (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.

NEE – Operating Revenue – Unrealized Losses – Refer to Note 3 to the financial statements

Critical Audit Matter Description

NEE enters into complex energy derivatives and transacts in certain markets that are thinly traded, which may result in subjective estimates of fair value that include unobservable inputs. Changes in the derivatives’ fair value for power purchases and sales, fuel sales and trading activities are primarily recognized on a net basis in operating revenues. For the year ended December 31, 2021, unrealized losses associated with Level 3 transactions of $924 million are included in operating revenues in the consolidated statement of income of NEE.

Given management uses complex proprietary models and unobservable inputs to estimate the fair value of Level 3 derivative assets and liabilities, performing audit procedures to evaluate the appropriateness of these models and inputs required a high degree of auditor judgment and an increased extent of effort, including the need to involve our firm specialists who possess significant quantitative and modeling expertise.

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How the Critical Audit Matter Was Addressed in the Audit

Our audit procedures related to operating revenue – unrealized losses included the following, among others:

•We tested the effectiveness of controls relating to commodity valuation models, their related Level 3 unobservable inputs, and market data validation.

•We selected a sample of transactions, obtained an understanding of the business rationale of transactions, and read the underlying contractual agreements.

•We used personnel in our firm who specialize in energy transacting to independently value Level 3 transactions. For certain fair value models, we used our firm specialists to directly test the underlying assumptions of the unobservable inputs used by management.

•We evaluated NEE’s disclosures related to the proprietary models and unobservable inputs to estimate the fair value of Level 3 derivative assets and liabilities, including the balances recorded and significant assumptions.

FPL – Impact of Rate Regulation on the Financial Statements – Refer to Note 1 to the financial statements

Critical Audit Matter Description

FPL is subject to rate regulation by the Florida Public Service Commission (the “FPSC”), which has jurisdiction with respect to the rates of electric distribution companies. Management has determined it meets the requirements under accounting principles generally accepted in the United States of America to prepare its financial statements applying the specialized rules to account for the effects of cost-based rate regulation. Accounting for the economics of rate regulation impacts multiple financial statement line items and disclosures, such as property, plant, and equipment; regulatory assets and liabilities; operating revenues; operation and maintenance expense; and depreciation expense.

Rates are determined and approved in regulatory proceedings based on an analysis of FPL’s costs to provide utility service and a return on, and recovery of, FPL’s investment in the assets required to deliver utility service. Accounting guidance for FPL’s regulated operations provides that rate-regulated entities report assets and liabilities consistent with the recovery of those incurred costs in rates, if it is probable that such rates will be charged and collected. The FPSC has the authority to disallow recovery of costs that it considers excessive or imprudently incurred. Future FPSC decisions could impact the accounting for regulated operations, including decisions about the amount of allowable costs and any refunds that may be required. As a result of this cost-based regulation, FPL follows the accounting guidance that allows regulators to create assets and impose liabilities, based on the probability of future cash flows, 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.

We identified the impact of rate regulation as a critical audit matter due to the requirement to have auditors with deep knowledge of and significant experience with accounting for rate regulation and the rate setting process due to its inherent complexities.

How the Critical Audit Matter Was Addressed in the Audit

Our audit procedures related to the impact of rate regulation included the following, among others:

•We tested the effectiveness of management’s controls over the evaluation of the likelihood of (1) the recovery in future rates of costs incurred as property, plant, and equipment and deferred as regulatory assets, and (2) a refund or a future reduction in rates that should be reported as regulatory liabilities. We also tested the effectiveness of management’s controls over the initial recognition of amounts as property, plant, and equipment and regulatory assets or liabilities; the depreciation and amortization of such amounts in accordance with FPSC orders; and the monitoring and evaluation of regulatory developments that may affect the likelihood of recovering costs recognized as property, plant and equipment and regulatory assets in future rates or of a refund or future reduction in rates that should be recognized as a regulatory liability.

•We evaluated FPL’s disclosures related to the impacts of rate regulation, including the balances recorded and regulatory developments.

•We assessed the likelihood of (1) recovery of recorded regulatory assets and (2) obligations requiring future reductions in rates by obtaining, reading and evaluating relevant regulatory orders issued by the FPSC to FPL, including the December 2, 2021 order adopting the stipulation of settlement for FPL's 2021 rate agreement. We also evaluated such regulatory orders and other publicly available filings made by FPL and compared them to management’s recorded regulatory asset and liability balances for completeness.

DELOITTE & TOUCHE LLP

Boca Raton, Florida

February 17, 2022

We have served as NEE’s and FPL’s auditor since 1950.

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NEXTERA ENERGY, INC.

CONSOLIDATED STATEMENTS OF INCOME

(millions, except per share amounts)

	Years Ended December 31,
	2021		2020		2019
OPERATING REVENUES	$	17,069	$	17,997	$	19,204
OPERATING EXPENSES
Fuel, purchased power and interchange	4,527		3,539		4,363
Other operations and maintenance	3,953		3,751		3,640
Storm restoration costs	28		183		234
Depreciation and amortization	3,924		4,052		4,216
Taxes other than income taxes and other – net	1,801		1,709		1,804
Total operating expenses – net	14,233		13,234		14,257
GAINS ON DISPOSAL OF BUSINESSES/ASSETS – NET	77		353		406
OPERATING INCOME	2,913		5,116		5,353
OTHER INCOME (DEDUCTIONS)
Interest expense	(1,270)		(1,950)		(2,249)
Equity in earnings (losses) of equity method investees	666		(1,351)		66
Allowance for equity funds used during construction	142		93		67
Gains on disposal of investments and other property – net	70		50		55
Change in unrealized gains (losses) on equity securities held in NEER's nuclear decommissioning funds – net	267		163		238
Other net periodic benefit income	257		200		185
Other – net	130		92		121
Total other income (deductions) – net	262		(2,703)		(1,517)
INCOME BEFORE INCOME TAXES	3,175		2,413		3,836
INCOME TAXES	348		44		448
NET INCOME	2,827		2,369		3,388
NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	746		550		381
NET INCOME ATTRIBUTABLE TO NEE	$	3,573	$	2,919	$	3,769
Earnings per share attributable to NEE:
Basic	$	1.82	$	1.49	$	1.95
Assuming dilution	$	1.81	$	1.48	$	1.94

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

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NEXTERA ENERGY, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(millions)

	Years Ended December 31,
	2021		2020		2019
NET INCOME	$	2,827	$	2,369	$	3,388
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX
Reclassification of unrealized losses on cash flow hedges from accumulated other comprehensive income (loss) to net income (net of $2 tax benefit, $4 tax benefit and $8 tax expense, respectively)	6		12		29
Net unrealized gains (losses) on available for sale securities:
Net unrealized gains (losses) on securities still held (net of $4 tax benefit, $4 tax expense and $8 tax expense, respectively)	(11)		12		20
Reclassification from accumulated other comprehensive income (loss) to net income (net of $2 tax expense, $1 tax expense and $1 tax benefit, respectively)	(4)		(3)		(2)
Defined benefit pension and other benefits plans:
Net unrealized gain (loss) and unrecognized prior service benefit (cost) (net of $30 tax expense, $11 tax expense and $14 tax benefit, respectively)	95		37		(46)
Reclassification from accumulated other comprehensive income (loss) to net income (net of $1 tax benefit, $1 tax benefit and $1 tax benefit, respectively)	5		2		(3)
Net unrealized gains (losses) on foreign currency translation	(1)		13		22
Other comprehensive income related to equity method investees (net of less than $1 tax expense, less than $1 tax expense and $0 tax expense, respectively)	1		1		1
Total other comprehensive income, net of tax	91		74		21
IMPACT OF DISPOSAL OF A BUSINESS (NET OF $19 TAX BENEFIT)	—		10		—
COMPREHENSIVE INCOME	2,918		2,453		3,409
COMPREHENSIVE LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	747		543		380
COMPREHENSIVE INCOME ATTRIBUTABLE TO NEE	$	3,665	$	2,996	$	3,789

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

61

NEXTERA ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(millions, except par value)

	December 31,
	2021		2020
ASSETS
Current assets:
Cash and cash equivalents	$	639	$	1,105
Customer receivables, net of allowances of $35 and $67, respectively	3,378		2,263
Other receivables	730		711
Materials, supplies and fuel inventory	1,561		1,552
Regulatory assets	1,125		377
Derivatives	689		570
Other	1,166		804
Total current assets	9,288		7,382
Other assets:
Property, plant and equipment – net ($20,521 and $18,084 related to VIEs, respectively)	99,348		91,803
Special use funds	8,922		7,779
Investment in equity method investees	6,159		5,728
Prepaid benefit costs	2,243		1,707
Regulatory assets	4,578		3,712
Derivatives	1,135		1,647
Goodwill	4,844		4,254
Other	4,395		3,672
Total other assets	131,624		120,302
TOTAL ASSETS	$	140,912	$	127,684
LIABILITIES, REDEEMABLE NONCONTROLLING INTERESTS AND EQUITY
Current liabilities:
Commercial paper	$	1,382	$	1,551
Other short-term debt	700		458
Current portion of long-term debt ($58 and $27 related to VIEs, respectively)	1,785		4,138
Accounts payable ($752 and $1,433 related to VIEs, respectively)	6,935		4,615
Customer deposits	485		474
Accrued interest and taxes	525		519
Derivatives	1,263		311
Accrued construction-related expenditures	1,378		991
Regulatory liabilities	289		245
Other	2,695		2,256
Total current liabilities	17,437		15,558
Other liabilities and deferred credits:
Long-term debt ($1,125 and $493 related to VIEs, respectively)	50,960		41,944
Asset retirement obligations	3,082		3,057
Deferred income taxes	8,310		8,020
Regulatory liabilities	11,273		10,735
Derivatives	1,713		1,199
Other	2,468		2,242
Total other liabilities and deferred credits	77,806		67,197
TOTAL LIABILITIES	95,243		82,755
COMMITMENTS AND CONTINGENCIES
REDEEMABLE NONCONTROLLING INTERESTS – VIE	245		—
EQUITY
Common stock ($0.01 par value, authorized shares – 3,200; outstanding shares – 1,963 and 1,960, respectively)	20		20
Additional paid-in capital	11,271		11,222
Retained earnings	25,911		25,363
Accumulated other comprehensive loss	—		(92)
Total common shareholders' equity	37,202		36,513
Noncontrolling interests ($8,217 and $8,413 related to VIEs, respectively)	8,222		8,416
TOTAL EQUITY	45,424		44,929
TOTAL LIABILITIES, REDEEMABLE NONCONTROLLING INTERESTS AND EQUITY	$	140,912	$	127,684

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

62

NEXTERA ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(millions)

	Years Ended December 31,
	2021		2020		2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	2,827	$	2,369	$	3,388
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	3,924		4,052		4,216
Nuclear fuel and other amortization	290		263		262
Unrealized losses (gains) on marked to market derivative contracts – net	2,005		533		(108)
Foreign currency transaction losses (gains)	(94)		45		17
Deferred income taxes	436		(78)		258
Cost recovery clauses and franchise fees	(599)		(121)		155
Equity in losses (earnings) of equity method investees	(666)		1,351		(66)
Distributions of earnings from equity method investees	526		456		438
Gains on disposal of businesses, assets and investments – net	(146)		(403)		(461)
Recoverable storm-related costs	(138)		(69)		(180)
Other – net	(326)		189		(141)
Changes in operating assets and liabilities:
Current assets	(1,267)		(364)		123
Noncurrent assets	(324)		(234)		(93)
Current liabilities	1,053		(6)		116
Noncurrent liabilities	52		—		231
Net cash provided by operating activities	7,553		7,983		8,155
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL Segment	(6,626)		(6,477)		(5,560)
Acquisition and capital expenditures of Gulf Power	(782)		(1,012)		(5,165)
Independent power and other investments of NEER	(8,247)		(6,851)		(6,385)
Nuclear fuel purchases	(275)		(245)		(315)
Other capital expenditures	(147)		(25)		(37)
Sale of independent power and other investments of NEER	2,761		1,012		1,316
Proceeds from sale or maturity of securities in special use funds and other investments	4,995		3,916		4,008
Purchases of securities in special use funds and other investments	(5,310)		(4,100)		(4,160)
Other – net	40		83		121
Net cash used in investing activities	(13,591)		(13,699)		(16,177)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt, including premiums and discounts	16,683		12,404		13,905
Retirements of long-term debt	(9,594)		(6,103)		(5,492)
Proceeds from differential membership investors	2,779		3,522		1,604
Net change in commercial paper	(169)		(965)		(234)
Proceeds from other short-term debt	—		2,158		200
Repayments of other short-term debt	(257)		(2,100)		(4,765)
Payments from (to) related parties under a cash sweep and credit support agreement – net	47		(2)		(54)
Issuances of common stock/equity units – net	14		(92)		1,494
Proceeds from sale of noncontrolling interests	65		501		99
Dividends on common stock	(3,024)		(2,743)		(2,408)
Other – net	(737)		(406)		(476)
Net cash provided by financing activities	5,807		6,174		3,873
Effects of currency translation on cash, cash equivalents and restricted cash	1		(20)		4
Net increase (decrease) in cash, cash equivalents and restricted cash	(230)		438		(4,145)
Cash, cash equivalents and restricted cash at beginning of year	1,546		1,108		5,253
Cash, cash equivalents and restricted cash at end of year	$	1,316	$	1,546	$	1,108
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)	$	1,323	$	1,432	$	1,799
Cash paid (received) for income taxes – net	$	(69)	$	235	$	184
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	$	4,995	$	4,445	$	3,573
Increase in property, plant and equipment related to an acquisition	$	—	$	68	$	—
Decrease in joint venture investments related to an acquisition	$	—	$	145	$	—

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

63

NEXTERA ENERGY, INC.

CONSOLIDATED STATEMENTS OF EQUITY

(millions)

	Common Stock			Additional Paid-In Capital		Accumulated Other Comprehensive Income (Loss)		Retained Earnings		Total Common Shareholders' Equity		Non- controlling Interests		Total Equity		Redeemable Non-controlling Interests
	Shares	Aggregate Par Value
Balances, December 31, 2018	1,912	$	19	$	10,476	$	(188)	$	23,837	$	34,144	$	3,269	$	37,413	$	468
Net income (loss)	—	—		—		—		3,769		3,769		(371)				(9)
Issuances of common stock/equity units – net	40	—		1,470		—		—		1,470		—				—
Share-based payment activity	4	—		164		—		—		164		—				—
Dividends on common stock(a)	—	—		—		—		(2,408)		(2,408)		—				—
Other comprehensive income	—	—		—		20		—		20		1				—
Premium on equity units	—	—		(120)		—		—		(120)		—				—
Other differential membership interest activity	—	—		(20)		—		—		(20)		1,270				29
Other	—	1		(15)		(1)		1		(14)		186				(1)
Balances, December 31, 2019	1,956	20		11,955		(169)		25,199		37,005		4,355		$	41,360	487
Net income (loss)	—	—		—		—		2,919		2,919		(546)				(4)
Issuances of common stock/equity units – net	—	—		(92)		—		—		(92)		—				—
Share-based payment activity	4	—		153		—		—		153		—				—
Dividends on common stock(a)	—	—		—		—		(2,743)		(2,743)		—				—
Other comprehensive income	—	—		—		67		—		67		7				—
Impact of disposal of a business	—	—		—		10		—		10		—				—
Adoption of accounting standards update(b)	—	—		—		—		(11)		(11)		—				—
Premium on equity units	—	—		(587)		—		—		(587)		—				—
Other differential membership interests activity	—	—		(36)		—		—		(36)		3,809				(483)
Sale of noncontrolling interests	—	—		(169)		—		—		(169)		689				—
Other	—	—		(2)		—		(1)		(3)		102				—
Balances, December 31, 2020	1,960	20		11,222		(92)		25,363		36,513		8,416		$	44,929	—
Net income (loss)	—	—		—		—		3,573		3,573		(748)				2
Share-based payment activity	3	—		132		—		—		132		—				—
Dividends on common stock(a)	—	—		—		—		(3,024)		(3,024)		—				—
Other comprehensive income (loss)	—	—		—		92		—		92		(1)				—
Other differential membership interests activity (c)	—	—		(26)		—		—		(26)		363				243
Other	—	—		(57)		—		(1)		(58)		192				—
Balances, December 31, 2021	1,963	$	20	$	11,271	$	—	$	25,911	$	37,202	$	8,222	$	45,424	$	245

_________________________

(a)Dividends per share were $1.54, $1.40 and $1.25 for the years ended December 31, 2021, 2020 and 2019, respectively.

(b)See Note 1 – Measurement of Credit Losses on Financial Instruments.

(c)See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

64

FLORIDA POWER & LIGHT COMPANY

CONSOLIDATED STATEMENTS OF INCOME

(millions)

	Years Ended December 31,
	2021		2020(a)		2019(a)
OPERATING REVENUES	$	14,102	$	13,060	$	13,680
OPERATING EXPENSES
Fuel, purchased power and interchange	3,956		3,060		3,802
Other operations and maintenance	1,803		1,707		1,790
Storm restoration costs	28		183		234
Depreciation and amortization	2,266		2,526		2,771
Taxes other than income taxes and other – net	1,533		1,464		1,504
Total operating expenses – net	9,586		8,940		10,101
OPERATING INCOME	4,516		4,120		3,579
OTHER INCOME (DEDUCTIONS)
Interest expense	(615)		(641)		(649)
Allowance for equity funds used during construction	132		87		66
Other – net	11		2		7
Total other deductions – net	(472)		(552)		(576)
INCOME BEFORE INCOME TAXES	4,044		3,568		3,003
INCOME TAXES	838		678		484
NET INCOME(b)	$	3,206	$	2,890	$	2,519

______________________

(a)Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

(b)FPL's comprehensive income is the same as reported net income.

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

65

FLORIDA POWER & LIGHT COMPANY

CONSOLIDATED BALANCE SHEETS

(millions, except share amount)

	December 31,
	2021		2020(a)
ASSETS
Current assets:
Cash and cash equivalents	$	55	$	25
Customer receivables, net of allowances of $11 and $44, respectively	1,297		1,141
Other receivables	350		405
Materials, supplies and fuel inventory	963		899
Regulatory assets	1,111		360
Other	142		182
Total current assets	3,918		3,012
Other assets:
Electric utility plant and other property – net	58,227		53,879
Special use funds	6,158		5,347
Prepaid benefit costs	1,657		1,550
Regulatory assets	4,343		3,399
Goodwill	2,989		2,989
Other	775		825
Total other assets	74,149		67,989
TOTAL ASSETS	$	78,067	$	71,001
LIABILITIES AND EQUITY
Current liabilities:
Commercial paper	$	1,382	$	1,551
Other short-term debt	200		200
Current portion of long-term debt	536		354
Accounts payable	1,318		874
Customer deposits	478		468
Accrued interest and taxes	322		300
Accrued construction-related expenditures	601		423
Regulatory liabilities	278		224
Other	643		948
Total current liabilities	5,758		5,342
Other liabilities and deferred credits:
Long-term debt	17,974		16,882
Asset retirement obligations	2,049		1,871
Deferred income taxes	7,137		6,519
Regulatory liabilities	11,053		10,600
Other	502		559
Total other liabilities and deferred credits	38,715		36,431
TOTAL LIABILITIES	44,473		41,773
COMMITMENTS AND CONTINGENCIES
EQUITY
Common stock (no par value, 1,000 shares authorized, issued and outstanding)	1,373		1,373
Additional paid-in capital	19,936		18,236
Retained earnings	12,285		9,619
TOTAL EQUITY	33,594		29,228
TOTAL LIABILITIES AND EQUITY	$	78,067	$	71,001

_________________________

(a)Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

66

FLORIDA POWER & LIGHT COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(millions)

	Years Ended December 31,
	2021		2020(a)		2019(a)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	3,206	$	2,890	$	2,519
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	2,266		2,526		2,771
Nuclear fuel and other amortization	174		167		178
Deferred income taxes	752		629		45
Cost recovery clauses and franchise fees	(599)		(121)		155
Recoverable storm-related costs	(138)		(69)		(180)
Other – net	(157)		35		(5)
Changes in operating assets and liabilities:
Current assets	(49)		(164)		(42)
Noncurrent assets	(114)		(77)		22
Current liabilities	20		31		50
Noncurrent liabilities	(3)		(31)		(12)
Net cash provided by operating activities	5,358		5,816		5,501
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(7,411)		(7,476)		(6,290)
Nuclear fuel purchases	(159)		(203)		(195)
Proceeds from sale or maturity of securities in special use funds	3,308		2,488		2,729
Purchases of securities in special use funds	(3,394)		(2,567)		(2,854)
Other – net	15		65		10
Net cash used in investing activities	(7,641)		(7,693)		(6,600)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt, including premiums and discounts	2,588		3,003		2,998
Retirements of long-term debt	(1,304)		(1,603)		(200)
Net change in commercial paper	(169)		(123)		418
Proceeds from other short-term debt	—		—		200
Capital contributions from NEE	1,700		2,750		359
Dividends to NEE	(540)		(2,210)		(2,620)
Other – net	(44)		(44)		(46)
Net cash provided by financing activities	2,231		1,773		1,109
Net increase (decrease) in cash, cash equivalents and restricted cash	(52)		(104)		10
Cash, cash equivalents and restricted cash at beginning of year	160		264		254
Cash, cash equivalents and restricted cash at end of year	$	108	$	160	$	264
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)	$	586	$	620	$	614
Cash paid (received) for income taxes – net	$	(1)	$	105	$	584
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	$	1,107	$	698	$	914
NEE's noncash contribution of a consolidated subsidiary – net	$	—	$	—	$	4,436

_________________________

(a) Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

67

FLORIDA POWER & LIGHT COMPANY

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDER'S EQUITY(a)

(millions)

	Common Stock		Additional Paid-In Capital		Retained Earnings		Common Shareholder's Equity
Balances, December 31, 2018	$	1,373	$	10,601	$	9,040	$	21,014
Net income	—		—		2,519
Capital contributions from NEE	—		359		—
Dividends to NEE	—		—		(2,620)
NEE's contribution of a consolidated subsidiary	—		4,525		—
Balances, December 31, 2019	1,373		15,485		8,939		$	25,797
Net income	—		—		2,890
Capital contributions from NEE	—		2,750		—
Dividends to NEE	—		—		(2,210)
Other	—		1		—
Balances, December 31, 2020	1,373		18,236		9,619		$	29,228
Net income	—		—		3,206
Capital contributions from NEE	—		1,700		—
Dividends to NEE	—		—		(540)
Balances, December 31, 2021	$	1,373	$	19,936	$	12,285	$	33,594

_________________________

(a)2020 and 2019 amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

68

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Years Ended December 31, 2021, 2020 and 2019

1. 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. The FPL segment (FPL, excluding Gulf Power, related purchase accounting adjustments and eliminating entries) and the Gulf Power segment (Gulf Power) continued to be operating segments of NEE, as well as FPL, through 2021. 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 Rate Regulation – Base Rates Effective January 2022 through December 2025 below). The merger of FPL and Gulf Power Company was a merger between entities under common control, which required it to be accounted for as if the merger occurred since the inception of common control, with prior periods retrospectively adjusted to furnish comparative information. Accordingly, FPL's consolidated financial statements have been retrospectively adjusted to include the historical results and financial position of the common control merger prior to the merger date. See Note 6 – Merger of FPL and Gulf Power Company.

FPL's principal business is a rate-regulated electric utility which supplies electric service to more than 5.7 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 ownership interests in joint ventures. NEER participates in natural gas, natural gas liquids and oil production primarily through operating and non-operating ownership interests and in pipeline infrastructure through either wholly owned subsidiaries or noncontrolling or joint venture interests. NEER also invests in rate-regulated transmission facilities and transmission lines that connect its electric generation facilities to the electric grid through controlled and consolidated entities.

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 contingent assets and liabilities. Actual results could differ from those estimates.

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 and 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 provide 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 $852 million, $800 million and $838 million in 2021, 2020 and 2019, 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.

69

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

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,
	2021		2020		2021		2020
	(millions)
Regulatory assets:
Current:
Early retirement of generation facilities and transmission assets(a)	$	140	$	36	$	140	$	36
Acquisition of purchased power agreements(b)	141		161		141		161
Deferred clause and franchise expenses	698		28		698		28
Other	146		152		132		135
Total	$	1,125	$	377	$	1,111	$	360
Noncurrent:
Early retirement of generation facilities and transmission assets(a)	$	2,233	$	1,438	$	2,233	$	1,438
Acquisition of purchased power agreements(b)	332		473		332		473
Accrued asset removal costs(c)	263		—		263		—
Other	1,750		1,801		1,515		1,488
Total	$	4,578	$	3,712	$	4,343	$	3,399
Regulatory liabilities:
Current:
Deferred clause revenues	$	274	$	215	$	274	$	215
Other	15		30		4		9
Total	$	289	$	245	$	278	$	224
Noncurrent:
Asset retirement obligation regulatory expense difference	$	4,290	$	3,583	$	4,290	$	3,583
Accrued asset removal costs(c)	782		1,206		752		1,179
Deferred taxes	4,561		4,698		4,457		4,594
Other	1,640		1,248		1,554		1,244
Total	$	11,273	$	10,735	$	11,053	$	10,600

______________________

(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)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, 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 underrecovery or overrecovery. Any underrecovered costs or overrecovered revenues are collected from or returned to customers in subsequent periods.

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. 

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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 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) is 10.60%, with a range of 9.70% to 11.70%. If FPL's earned regulatory ROE falls below 9.70%, FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.70%, any party with standing may seek a review of FPL's retail base rates. If the average 30-year U.S. Treasury rate is 2.49% or greater over a consecutive six-month period, the authorized regulatory ROE will increase to 10.80% with a range of 9.80% to 11.80%. If triggered, the increase in the authorized regulatory ROE will not result in an incremental general base rate increase, but will apply for all other regulatory purposes, including the SoBRA mechanism.

•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 limited to the amortization of $200 million of depreciation reserve surplus during the first year of the 2021 rate agreement.

•FPL is authorized to expand SolarTogether™, a voluntary community solar program that gives certain FPL electric customers an opportunity to participate directly in the expansion of solar energy 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 be able to prospectively adjust base rates after a review by the FPSC.

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.

Base Rates Effective January 2017 through December 2021 – In December 2016, the FPSC issued a final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2016 rate agreement). Key elements of the 2016 rate agreement, which became effective in January 2017, provided for, among other things, the following:

•new retail base rates and charges which resulted in the following increases in annualized retail base revenues:

◦$400 million beginning January 1, 2017;

◦$211 million beginning January 1, 2018; and

◦$200 million beginning April 1, 2019 for a new approximately 1,720 MW natural gas-fired combined-cycle unit in Okeechobee County, Florida that achieved commercial operation on March 31, 2019;

•additional base rate increases in 2018 through 2020 associated with the addition of approximately 1,200 MW of new solar generating capacity that became operational during that timeframe;

•regulatory ROE of 10.55%, with a range of 9.60% to 11.60%;

•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%; and

•an interim cost recovery mechanism for storm restoration costs. See Storm Funds, Storm Reserves and Storm Cost Recovery below.

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

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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, 2021 and 2020, convertible ITCs, net of amortization, were approximately $755 million ($116 million at FPL) and $791 million ($122 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. These new rates are expected to decrease depreciation expense. 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 noncurrent regulatory liabilities at December 31, 2020 on NEE's and FPL's consolidated balance sheets. The FPL segment used available reserve amortization to offset all of the storm restoration costs that were expensed during 2019 through 2021. See Storm Funds, Storm Reserves and Storm Cost Recovery below. 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, 2021 and 2020, NEER's capitalized development costs totaled approximately $831 million and $571 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. In 2019, NEER determined it was no longer moving forward with the construction of a 220 MW wind facility due to unresolved permitting issues. NEE recorded charges of approximately $72 million ($54 million after tax), which are included in taxes other than income taxes and other – net in NEE’s consolidated statements of income for the year ended December 31, 2019, primarily related to the write-off of capitalized construction costs.

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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 subsequently 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 subsequently allocated to expense using a systematic and rational method over the asset's estimated useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense, which is included in depreciation and amortization expense in NEE's consolidated statements of income. Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the asset retirement cost, or income when asset retirement cost is depleted.

Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs – 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, and provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the dismantlement of St. Lucie Unit No. 2 in 2043. These studies also assume that FPL will be storing spent fuel on site pending removal to a United States (U.S.) government facility. 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 $10.2 billion, or $2.4 billion expressed in 2021 dollars. The ultimate costs of decommissioning reflect the application submitted to the U.S. Nuclear Regulatory Commission (NRC) for the extension of 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 2021, 2020 and 2019 fund earnings on decommissioning funds were approximately $173 million, $132 million and $125 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, 2021, FPL's portion of the ultimate cost to dismantle its other generation units is approximately $2.5 billion, or $1.2 billion expressed in 2021 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

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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, 2021 and 2020, NEER's ARO was approximately $1.1 billion and $1.2 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 $9.4 billion, or $2.1 billion expressed in 2021 dollars. The ultimate cost to dismantle NEER's wind and solar facilities is estimated to be approximately $2.0 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, 2021 and 2020, NEE had approximately $677 million ($53 million for FPL) and $441 million ($135 million for FPL), respectively, of restricted cash, of which approximately $677 million ($53 million for FPL) and $374 million ($93 million for FPL), respectively, are included in current other assets and the remaining balances are included in noncurrent 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 $121 million is netted against derivative assets and $172 million is netted against derivative liabilities at December 31, 2021 and $183 million is netted against derivative assets and $136 million is netted against derivative liabilities at December 31, 2020. 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. See also Note 4 – Special Use Funds.

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.

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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, 2021, 2020 and 2019, NEE recorded approximately $146 million, $94 million and $32 million of bad debt expense, including credit losses, respectively, which are included in O&M expenses in NEE’s consolidated statements of income. The amount for the year ended December 31, 2021 primarily relates 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 are included in noncurrent other assets on NEE's consolidated balance sheet related to the February 2021 weather event.

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 and property insurance reserve funds (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 and property insurance reserves (storm reserves). 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 2021, 2020 and 2019, FPL’s service area was impacted by hurricanes and tropical storms, which resulted in the recording of incremental storm restoration costs. The FPL segment 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.

Restoration costs associated with multiple storms since 2018 that impacted FPL's customers in the former Gulf Power service area are being collected from northwest Florida customers through a storm damage surcharge through late 2024 and are recorded as regulatory assets. 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. As of December 31, 2020, the balance was $347 million, of which $100 million and $247 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.

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Goodwill and Other Intangible Assets – NEE's goodwill and other intangible assets are as follows:

	Weighted- Average Useful Lives	December 31,
		2021		2020
	(years)	(millions)
Goodwill (by reporting unit):
FPL segment:
Florida City Gas		$	292	$	292
Other		9		9
Gulf Power (see Note 6 – Merger of FPL and Gulf Power Company)		2,688		2,688
NEER segment:
Rate-regulated transmission (see Note 6 – GridLiance)		1,206		614
Gas infrastructure		487		487
Customer supply and trading		95		93
Generation assets		56		60
Corporate and Other		11		11
Total goodwill		$	4,844	$	4,254
Other intangible assets not subject to amortization, primarily land easements		$	136	$	135
Other intangible assets subject to amortization:
Purchased power agreements	15	$	507	$	453
Other, primarily transportation contracts and customer lists	23	187		166
Total		694		619
Accumulated amortization		(88)		(61)
Total other intangible assets subject to amortization – net		$	606	$	558

NEE's, including FPL's, goodwill relates to various acquisitions which were accounted for using the purchase method of accounting. Other intangible assets are primarily included in noncurrent other assets on NEE's consolidated balance sheets. NEE's other intangible assets subject to amortization are amortized, primarily on a straight-line basis, over their estimated useful lives. Amortization expense was approximately $25 million, $27 million and $18 million for the years ended December 31, 2021, 2020 and 2019, respectively, and is expected to be approximately $16 million, $16 million, $18 million, $16 million and $16 million for 2022, 2023, 2024, 2025 and 2026, 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

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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, 2022. 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, 2022 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.

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 $3,780 million ($3,723 million for FPL) and $3,949 million ($3,890 million for FPL) at December 31, 2021 and 2020, respectively, and is being amortized in accordance with the regulatory treatment over the estimated lives of the assets or liabilities for which the deferred tax amount was initially recognized.

Production tax credits (PTCs) are recognized as wind energy is generated and sold based on a per kWh rate prescribed in applicable federal and state statutes and are recorded as a reduction of current income taxes payable, unless limited by tax law in which instance they are recorded as deferred tax assets. NEER recognizes ITCs as a reduction to income tax expense when the related energy property is placed into service. FPL recognizes ITCs as a reduction to income tax expense over the depreciable life of the related energy property. At December 31, 2021 and 2020, FPL’s accumulated deferred ITCs were approximately $1,054 million and $753 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, 2021, NEE had unrecognized tax benefits of approximately $125 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 and solar generation facilities, with generating capacity totaling approximately 11,226 MW and 1,894 MW, respectively, and battery storage capacity in operation or under construction totaling 220 MW at December 31, 2021, to third-party investors. NEE retains a controlling interest in the entities and therefore presents the Class B member interests as noncontrolling interests. Noncontrolling interests represents the portion of net assets in consolidated entities that are not owned by NEE and are reported as a component of equity in NEE’s consolidated balance sheet. The third-party investors are allocated earnings, tax attributes and cash flows in accordance with the respective limited liability company agreements. Those economics are allocated primarily to the third-party investors until they receive a targeted return (the flip date) and thereafter to NEE. NEE has the right to call the third-party interests at specified amounts if and when the flip date occurs. NEE has determined the allocation of economics between the controlling party and third-party investor should not follow the respective ownership percentages for each wind and solar project but rather the hypothetical liquidation of book value (HLBV) method based on the governing provisions in each respective limited liability company agreement. Under the HLBV method, the amounts of income and loss attributable to the noncontrolling interest reflects changes in the amount the owners would hypothetically receive at each balance sheet date under the respective liquidation provisions, assuming the net assets of these entities were liquidated at the recorded amounts, after taking into account any capital transactions, such as contributions and distributions, between the entities and the owners. At the point in time that the third-party investor, in hypothetical liquidation, would achieve its targeted return, NEE attributes the additional hypothetical proceeds to the Class B membership interests based on the call price. A loss attributable to noncontrolling interest on NEE’s consolidated statements of income represents earnings attributable to NEE.

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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 sheet as of December 31, 2021. These contingencies are expected to be resolved in 2022.

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 included 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 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 are currently under construction with expected in-service dates in the first half of 2022. Total cash proceeds for these two separate transactions totaled approximately $1.7 billion, subject to working capital and other adjustments. NEER will continue to consolidate the three projects currently under construction for accounting purposes. 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) is reflected in the gains on disposal of businesses/assets – net in NEE’s consolidated statements of income for the year ended December 31, 2021. In connection with the three facilities currently 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. The contract liabilities relate 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 is contingent on the enactment of a solar PTC by a specified date in 2022. The contract liabilities associated with the sale proceeds and the differential membership interests are also subject to the three facilities under construction achieving commercial operations by specified dates in the first half of 2022. The contract liabilities will be reversed and the sale recognized for accounting purposes if the contingencies are resolved in 2022. Otherwise, NextEra Energy Resources may be required to return proceeds related to differential membership interests and/or repurchase the facilities for up to $668 million. In addition, NextEra Energy Resources is responsible to pay for all construction costs related to the portfolio. At December 31, 2021, approximately $970 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 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 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.

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In December 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, in December 2020, 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) 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. In 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 at December 31, 2020. In connection with the solar-plus-storage facility transaction, approximately $155 million of cash received was recorded as a contract liability, which is included in current other liabilities on NEE's consolidated balance sheet at December 31, 2020. The solar-plus-storage facility achieved commercial operations in June 2021 and 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.

In 2019, subsidiaries of NextEra Energy Resources completed the sale of ownership interests in three wind generation facilities and three solar generation facilities, including noncontrolling interests in two of the solar facilities, located in the Midwest and West regions of the U.S. with a total net generating capacity of 611 MW to a NEP subsidiary for cash proceeds of approximately $1.0 billion, plus working capital of $12 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 $341 million ($259 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2019, which is included in gains on disposal of businesses/assets – net, and noncontrolling interests of approximately $118 million were recorded on NEE's consolidated balance sheet.

2. Revenue from Contracts with Customers

Revenue is recognized when control of the promised goods or services is transferred to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. The promised goods or services in the majority of NEE’s contracts with customers is, at FPL, for the delivery of electricity based on tariff rates approved by the FPSC and, at NEER, for the delivery of energy commodities and the availability of electric capacity and electric transmission.

FPL and NEER generate substantially all of NEE’s operating revenues, which primarily include revenues from contracts with customers, as well as derivative and lease transactions at NEER. For the vast majority of contracts with customers, NEE believes that the obligation to deliver energy, capacity or transmission is satisfied over time as the customer simultaneously receives and consumes benefits as NEE performs. In 2021, 2020 and 2019, NEE’s revenue from contracts with customers was approximately $18.8 billion ($14.1 billion at FPL), $17.0 billion ($13.0 billion at FPL) and $17.5 billion ($13.6 billion at FPL), respectively. NEE's and FPL's receivables are primarily associated with revenues earned from contracts with customers, as well as derivative and lease transactions at NEER, and consist of both billed and unbilled amounts, which are recorded in customer receivables and other receivables on NEE's and FPL's consolidated balance sheets. Receivables represent unconditional rights to consideration and reflect the differences in timing of revenue recognition and cash collections. For substantially all of NEE's and FPL's receivables, regardless of the type of revenue transaction from which the receivable originated, customer and counterparty credit risk is managed in the same manner and the terms and conditions of payment are similar. During 2021, NEER did not recognize approximately $180 million of revenue related to reimbursable expenses from a counterparty that are deemed not probable of collection. These reimbursable expenses arose from the impacts of the February 2021 weather event. These determinations were made based on assessments of the counterparty's creditworthiness and NEER's ability to collect.

FPL – FPL’s revenues are derived primarily from tariff-based sales that result from providing electricity to retail customers in Florida with no defined contractual term. Electricity sales to retail customers account for approximately 90% of FPL’s 2021 operating revenues, the majority of which are to residential customers. FPL’s retail customers receive a bill monthly based on the amount of monthly kWh usage with payment due monthly. For these types of sales, FPL recognizes revenue as electricity is delivered and billed to customers, as well as an estimate for electricity delivered and not yet billed. The billed and unbilled amounts represent the value of electricity delivered to the customer. At December 31, 2021 and 2020, FPL's unbilled revenues amounted to approximately $583 million and $454 million, respectively, and are included in customer receivables on NEE’s and FPL’s consolidated balance sheets. Certain contracts with customers contain a fixed price which primarily relate to certain power purchase agreements with maturity dates through 2041. As of December 31, 2021, FPL expects to record approximately $400 million of revenues related to the fixed capacity price components of such contracts over the remaining terms of the related

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contracts as the capacity is provided. These contracts also contain a variable price component for energy usage which FPL recognizes as revenue as the energy is delivered based on rates stipulated in the respective contracts.

NEER – NEER’s revenue from contracts with customers is derived primarily from the sale of energy commodities, electric capacity and electric transmission. For these types of sales, NEER recognizes revenue as energy commodities are delivered and as electric capacity and electric transmission are made available, consistent with the amounts billed to customers based on rates stipulated in the respective contracts as well as an accrual for amounts earned but not yet billed. The amounts billed and accrued represent the value of energy or transmission delivered and/or the capacity of energy or transmission available to the customer. Revenues yet to be earned under these contracts, which have maturity dates ranging from 2022 to 2053, will vary based on the volume of energy or transmission delivered and/or available. NEER’s customers typically receive bills monthly with payment due within 30 days. Certain contracts with customers contain a fixed price which primarily relate to electric capacity sales associated with independent system operator annual auctions through 2025 and certain power purchase agreements with maturity dates through 2034. As of December 31, 2021, NEER expects to record approximately $735 million of revenues related to the fixed price components of such contracts over the remaining terms of the related contracts as the capacity is provided.

3. Derivative Instruments

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, as well as interest rate and foreign currency exchange rate risk associated primarily with outstanding and expected future debt issuances and borrowings, and to optimize the value of NEER's power generation and gas infrastructure assets. NEE and FPL do not utilize hedge accounting for their cash flow and fair value hedges.

With respect to commodities related to NEE's competitive energy business, NEER employs risk management procedures to conduct its activities related to optimizing the value of its power generation and gas infrastructure assets, providing full energy and capacity requirements services primarily to distribution utilities, and engaging in power and fuel marketing and trading activities to take advantage of expected future favorable price movements and changes in the expected volatility of prices in the energy markets. These risk management activities involve the use of derivative instruments executed within prescribed limits to manage the risk associated with fluctuating commodity prices. Transactions in derivative instruments are executed on recognized exchanges or via the over-the-counter (OTC) markets, depending on the most favorable credit terms and market execution factors. For NEER's power generation and gas infrastructure assets, derivative instruments are used to hedge all or a portion of the expected output of these assets. These hedges are designed to reduce the effect of adverse changes in the wholesale forward commodity markets associated with NEER's power generation and gas infrastructure assets. With regard to full energy and capacity requirements services, NEER is required to vary the quantity of energy and related services based on the load demands of the customers served. For this type of transaction, derivative instruments are used to hedge the anticipated electricity quantities required to serve these customers and reduce the effect of unfavorable changes in the forward energy markets. Additionally, NEER takes positions in energy markets based on differences between actual forward market levels and management's view of fundamental market conditions, including supply/demand imbalances, changes in traditional flows of energy, changes in short- and long-term weather patterns and anticipated regulatory and legislative outcomes. NEER uses derivative instruments to realize value from these market dislocations, subject to strict risk management limits around market, operational and credit exposure.

Derivative instruments, when required to be marked to market, are recorded on NEE's and FPL's consolidated balance sheets as either an asset or liability measured at fair value. At FPL, substantially all changes in the derivatives' fair value are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the applicable fuel and purchased power cost recovery clause (fuel clause). For NEE's non-rate regulated operations, predominantly NEER, essentially all changes in the derivatives' fair value for power purchases and sales, fuel sales and trading activities are recognized on a net basis in operating revenues and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's consolidated statements of income. Settlement gains and losses are included within the line items in the consolidated statements of income to which they relate. Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the consolidated statements of income. For commodity derivatives, NEE believes that, where offsetting positions exist at the same location for the same time, the transactions are considered to have been netted and therefore physical delivery has been deemed not to have occurred for financial reporting purposes. Settlements related to derivative instruments are primarily recognized in net cash provided by operating activities in NEE's and FPL's consolidated statements of cash flows.

For interest rate and foreign currency derivative instruments, all changes in the derivatives' fair value, as well as the transaction gain or loss on foreign denominated debt, are recognized in interest expense and the equity method investees' related activity is recognized in equity in earnings (losses) of equity method investees in NEE's consolidated statements of income. In addition, for the years ended December 31, 2020 and 2019, NEE reclassified from AOCI approximately $26 million ($6 million after tax), of which $23 million was reclassified to gains on disposal of businesses/assets – net (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests) with the balance to interest expense, and $11 million ($8 million after tax) to

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interest expense, respectively, because it became probable that related future transactions being hedged would not occur. At December 31, 2021, NEE's AOCI included amounts related to discontinued interest rate cash flow hedges with expiration dates through March 2035 and foreign currency cash flow hedges with expiration dates through September 2030. Approximately $6 million of net losses included in AOCI at December 31, 2021 are expected to be reclassified into earnings within the next 12 months as the principal and/or interest payments are made. Such amounts assume no change in scheduled principal payments.

Fair Value Measurements of Derivative Instruments – The fair value of assets and liabilities are determined using either unadjusted quoted prices in active markets (Level 1) or pricing inputs that are observable (Level 2) whenever that information is available and using unobservable inputs (Level 3) to estimate fair value only when relevant observable inputs are not available. NEE and FPL use several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those assets and liabilities that are measured at fair value on a recurring basis. NEE's and FPL's assessment of the significance of any particular input to the fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Non-performance risk, including the consideration of a credit valuation adjustment, is also considered in the determination of fair value for all assets and liabilities measured at fair value.

NEE and FPL measure the fair value of commodity contracts using a combination of market and income approaches utilizing prices observed on commodities exchanges and in the OTC markets, or through the use of industry-standard valuation techniques, such as option modeling or discounted cash flows techniques, incorporating both observable and unobservable valuation inputs. The resulting measurements are the best estimate of fair value as represented by the transfer of the asset or liability through an orderly transaction in the marketplace at the measurement date.

Most exchange-traded derivative assets and liabilities are valued directly using unadjusted quoted prices. For exchange-traded derivative assets and liabilities where the principal market is deemed to be inactive based on average daily volumes and open interest, the measurement is established using settlement prices from the exchanges, and therefore considered to be valued using other observable inputs.

NEE, through its subsidiaries, including FPL, also enters into OTC commodity contract derivatives. The majority of these contracts are transacted at liquid trading points, and the prices for these contracts are verified using quoted prices in active markets from exchanges, brokers or pricing services for similar contracts.

NEE, through NEER, also enters into full requirements contracts, which, in most cases, meet the definition of derivatives and are measured at fair value. These contracts typically have one or more inputs that are not observable and are significant to the valuation of the contract. In addition, certain exchange and non-exchange traded derivative options at NEE have one or more significant inputs that are not observable, and are valued using industry-standard option models.

In all cases where NEE and FPL use significant unobservable inputs for the valuation of a commodity contract, consideration is given to the assumptions that market participants would use in valuing the asset or liability. The primary input to the valuation models for commodity contracts is the forward commodity curve for the respective instruments. Other inputs include, but are not limited to, assumptions about market liquidity, volatility, correlation and contract duration as more fully described below in Significant Unobservable Inputs Used in Recurring Fair Value Measurements. In instances where the reference markets are deemed to be inactive or do not have transactions for a similar contract, the derivative assets and liabilities may be valued using significant other observable inputs and potentially significant unobservable inputs. In such instances, the valuation for these contracts is established using techniques including extrapolation from or interpolation between actively traded contracts, or estimated basis adjustments from liquid trading points. NEE and FPL regularly evaluate and validate the inputs used to determine fair value by a number of methods, consisting of various market price verification procedures, including the use of pricing services and multiple broker quotes to support the market price of the various commodities. In all cases where there are assumptions and models used to generate inputs for valuing derivative assets and liabilities, the review and verification of the assumptions, models and changes to the models are undertaken by individuals that are independent of those responsible for estimating fair value.

NEE uses interest rate contracts and foreign currency contracts to mitigate and adjust interest rate and foreign currency exchange exposure related primarily to certain outstanding and expected future debt issuances and borrowings when deemed appropriate based on market conditions or when required by financing agreements. NEE estimates the fair value of these derivatives using an income approach based on a discounted cash flows valuation technique utilizing the net amount of estimated future cash inflows and outflows related to the agreements.

The tables below present NEE's and FPL's gross derivative positions at December 31, 2021 and December 31, 2020, as required by disclosure rules. However, the majority of the underlying contracts are subject to master netting agreements and generally would not be contractually settled on a gross basis. Therefore, the tables below also present the derivative positions on a net basis, which reflect the offsetting of positions of certain transactions within the portfolio, the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral, as well as the location of the net derivative position on the consolidated balance sheets.

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	December 31, 2021
	Level 1		Level 2		Level 3		Netting(a)		Total
	(millions)
Assets:
NEE:
Commodity contracts	$	1,896	$	5,082	$	1,401	$	(6,622)	$	1,757
Interest rate contracts	$	—	$	106	$	—	$	(30)	76
Foreign currency contracts	$	—	$	8	$	—	$	(17)	(9)
Total derivative assets									$	1,824
FPL – commodity contracts	$	—	$	3	$	13	$	(3)	$	13
Liabilities:
NEE:
Commodity contracts	$	2,571	$	4,990	$	1,231	$	(6,594)	$	2,198
Interest rate contracts	$	—	$	739	$	—	$	(30)	709
Foreign currency contracts	$	—	$	86	$	—	$	(17)	69
Total derivative liabilities									$	2,976
FPL – commodity contracts	$	—	$	8	$	5	$	(3)	$	10
Net fair value by NEE balance sheet line item:
Current derivative assets(b)									$	689
Noncurrent derivative assets(c)									1,135
Total derivative assets									$	1,824
Current derivative liabilities(d)									$	1,263
Noncurrent derivative liabilities(e)									1,713
Total derivative liabilities									$	2,976
Net fair value by FPL balance sheet line item:
Current other assets									$	13
Current other liabilities									$	9
Noncurrent other liabilities									1
Total derivative liabilities									$	10

______________________

(a)Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the consolidated balance sheets and are recorded in customer receivables – net and accounts payable, respectively.

(b)Reflects the netting of approximately $150 million in margin cash collateral received from counterparties.

(c)Reflects the netting of approximately $56 million in margin cash collateral received from counterparties.

(d)Reflects the netting of approximately $6 million in margin cash collateral paid to counterparties.

(e)Reflects the netting of approximately $172 million in margin cash collateral paid to counterparties.

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	December 31, 2020
	Level 1		Level 2		Level 3		Netting(a)		Total
	(millions)
Assets:
NEE:
Commodity contracts	$	919	$	1,881	$	1,679	$	(2,325)	$	2,154
Interest rate contracts	$	—	$	81	$	—	$	(41)	40
Foreign currency contracts	$	—	$	57	$	—	$	(34)	23
Total derivative assets									$	2,217
FPL – commodity contracts	$	—	$	1	$	2	$	—	$	3
Liabilities:
NEE:
Commodity contracts	$	1,004	$	1,468	$	305	$	(2,277)	$	500
Interest rate contracts	$	—	$	1,042	$	—	$	(41)	1,001
Foreign currency contracts	$	—	$	43	$	—	$	(34)	9
Total derivative liabilities									$	1,510
FPL – commodity contracts	$	—	$	—	$	3	$	—	$	3
Net fair value by NEE balance sheet line item:
Current derivative assets									$	570
Noncurrent derivative assets(b)									1,647
Total derivative assets									$	2,217
Current derivative liabilities(c)									$	311
Noncurrent derivative liabilities									1,199
Total derivative liabilities									$	1,510
Net fair value by FPL balance sheet line item:
Current other assets									$	3
Current other liabilities									$	2
Noncurrent other liabilities									1
Total derivative liabilities									$	3

______________________

(a)Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the consolidated balance sheets and are recorded in customer receivables – net and accounts payable, respectively.

(b)Reflects the netting of approximately $184 million in margin cash collateral received from counterparties.

(c)Reflects the netting of approximately $136 million in margin cash collateral paid to counterparties.

At December 31, 2021 and 2020, NEE had approximately $56 million and $6 million (none at FPL), respectively, in margin cash collateral received from counterparties that was not offset against derivative assets in the above presentation. These amounts are included in current other liabilities on NEE's consolidated balance sheets. Additionally, at December 31, 2021 and 2020, NEE had approximately $673 million and $315 million (none at FPL), respectively, in margin cash collateral paid to counterparties that was not offset against derivative assets or liabilities in the above presentation. These amounts are included in current other assets on NEE's consolidated balance sheets.

Significant Unobservable Inputs Used in Recurring Fair Value Measurements – The valuation of certain commodity contracts requires the use of significant unobservable inputs. All forward price, implied volatility, implied correlation and interest rate inputs used in the valuation of such contracts are directly based on third-party market data, such as broker quotes and exchange settlements, when that data is available. If third-party market data is not available, then industry standard methodologies are used to develop inputs that maximize the use of relevant observable inputs and minimize the use of unobservable inputs. Observable inputs, including some forward prices, implied volatilities and interest rates used for determining fair value are updated daily to reflect the best available market information. Unobservable inputs which are related to observable inputs, such as illiquid portions of forward price or volatility curves, are updated daily as well, using industry standard techniques such as interpolation and extrapolation, combining observable forward inputs supplemented by historical market and other relevant data. Other unobservable inputs, such as implied correlations, block-to-hourly price shaping, customer migration rates from full requirements contracts and some implied volatility curves, are modeled using proprietary models based on historical data and industry standard techniques.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The significant unobservable inputs used in the valuation of NEE's commodity contracts categorized as Level 3 of the fair value hierarchy at December 31, 2021 are as follows:

Transaction Type	Fair Value at December 31, 2021				Valuation Technique(s)	Significant Unobservable Inputs	Range			Weighted-average(a)
	Assets		Liabilities
	(millions)
Forward contracts – power	$	433	$	204	Discounted cash flow	Forward price (per MWh(b))	$(5)	—	$140	$37
Forward contracts – gas	191		31		Discounted cash flow	Forward price (per MMBtu(c))	$2	—	$15	$3
Forward contracts – congestion	29		8		Discounted cash flow	Forward price (per MWh(b))	$(10)	—	$45	$—
Options – power	52		(1)		Option models	Implied correlations	32%	—	86%	52%
						Implied volatilities	8%	—	368%	81%
Options – primarily gas	356		347		Option models	Implied correlations	32%	—	86%	52%
						Implied volatilities	17%	—	295%	36%
Full requirements and unit contingent contracts	200		566		Discounted cash flow	Forward price (per MWh(b))	$2	—	$308	$64
						Customer migration rate(d)	—%	—	19%	2%
Forward contracts – other	140		76
Total	$	1,401	$	1,231

______________________

(a)Unobservable inputs were weighted by volume.

(b)Megawatt-hours

(c)One million British thermal units

(d)Applies only to full requirements contracts.

The sensitivity of NEE's fair value measurements to increases (decreases) in the significant unobservable inputs is as follows:

Significant Unobservable Input	Position	Impact on Fair Value Measurement
Forward price	Purchase power/gas	Increase (decrease)
	Sell power/gas	Decrease (increase)
Implied correlations	Purchase option	Decrease (increase)
	Sell option	Increase (decrease)
Implied volatilities	Purchase option	Increase (decrease)
	Sell option	Decrease (increase)
Customer migration rate	Sell power(a)	Decrease (increase)

————————————

(a)Assumes the contract is in a gain position.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The reconciliation of changes in the fair value of derivatives that are based on significant unobservable inputs is as follows:

	Years Ended December 31,
	2021				2020				2019
	NEE		FPL		NEE		FPL		NEE		FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year	$	1,374	$	(1)	$	1,207	$	(8)	$	647	$	(36)
Realized and unrealized gains (losses):
Included in earnings(a)	(1,488)		—		547		—		923		—
Included in other comprehensive income (loss)(b)	—		—		1		—		5		—
Included in regulatory assets and liabilities	8		8		2		2		1		1
Purchases	243		—		191		—		141		—
Sales(c)	—		—		114		—		—		—
Settlements	259		1		(562)		6		(356)		25
Issuances	(196)		—		(123)		—		(87)		—
Transfers in(d)	2		—		18		(1)		(5)		—
Transfers out(d)	(32)		—		(21)		—		(62)		2
Fair value of net derivatives based on significant unobservable inputs at December 31	$	170	$	8	$	1,374	$	(1)	$	1,207	$	(8)
Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date(e)	$	(924)	$	—	$	317	$	—	$	611	$	—

______________________

(a)For the years ended December 31, 2021, 2020 and 2019, realized and unrealized gains (losses) of approximately $(1,488) million, $569 million and $956 million are included in the consolidated statements of income in operating revenues and the balance is included in interest expense.

(b)Included in net unrealized gains (losses) on foreign currency translation in the consolidated statements of comprehensive income.

(c)See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

(d)Transfers into Level 3 were a result of decreased observability of market data. Transfers from Level 3 to Level 2 were a result of increased observability of market data.

(e)For the years ended December 31, 2021, 2020 and 2019, unrealized gains (losses) of approximately $(924) million, $317 million and $638 million are included in the consolidated statements of income in operating revenues and the balance is included in interest expense.

Income Statement Impact of Derivative Instruments – Gains (losses) related to NEE's derivatives are recorded in NEE's consolidated statements of income as follows:

	Years Ended December 31,
	2021		2020		2019
	(millions)
Commodity contracts(a) – operating revenues	$	(2,710)	$	352	$	762
Foreign currency contracts – interest expense	(89)		8		(7)
Interest rate contracts – interest expense	264		(421)		(699)
Losses reclassified from AOCI:
Interest rate contracts(b)	(7)		(35)		(32)
Foreign currency contracts – interest expense	(3)		(3)		(4)
Total	$	(2,545)	$	(99)	$	20

______________________

(a)For the years ended December 31, 2021, 2020 and 2019, FPL recorded gains of approximately $7 million, $6 million and $9 million, respectively, related to commodity contracts as regulatory liabilities on its consolidated balance sheets.

(b)For the year ended December 31, 2020, approximately $23 million was reclassified to gains on disposal of businesses/assets – net (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests); remaining balances were reclassified to interest expense on NEE's consolidated statements of income.

Notional Volumes of Derivative Instruments – The following table represents net notional volumes associated with derivative instruments that are required to be reported at fair value in NEE's and FPL's consolidated financial statements. The table includes significant volumes of transactions that have minimal exposure to commodity price changes because they are variably priced agreements. These volumes are only an indication of the commodity exposure that is managed through the use of derivatives. They do not represent net physical asset positions or non-derivative positions and the related hedges, nor do they represent NEE's and FPL's net economic exposure, but only the net notional derivative positions that fully or partially hedge the related asset positions. NEE and FPL had derivative commodity contracts for the following net notional volumes:

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	December 31, 2021				December 31, 2020
Commodity Type	NEE		FPL		NEE		FPL
	(millions)
Power	(103)	MWh	—		(90)	MWh	—
Natural gas	(1,290)	MMBtu	91	MMBtu	(607)	MMBtu	87	MMBtu
Oil	(33)	barrels	—		(6)	barrels	—

At December 31, 2021 and 2020, NEE had interest rate contracts with a notional amount of approximately $11.2 billion and a net notional amount of approximately $10.5 billion, respectively, and foreign currency contracts with a notional amount of approximately $1.0 billion and $1.0 billion, respectively.

Credit-Risk-Related Contingent Features – Certain derivative instruments contain credit-risk-related contingent features including, among other things, the requirement to maintain an investment grade credit rating from specified credit rating agencies and certain financial ratios, as well as credit-related cross-default and material adverse change triggers. At December 31, 2021 and 2020, the aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately $4.1 billion ($12 million for FPL) and $1.9 billion ($3 million for FPL), respectively.

If the credit-risk-related contingent features underlying these derivative agreements were triggered, certain subsidiaries of NEE, including FPL, could be required to post collateral or settle contracts according to contractual terms which generally allow netting of contracts in offsetting positions. Certain derivative contracts contain multiple types of credit-related triggers. To the extent these contracts contain a credit ratings downgrade trigger, the maximum exposure is included in the following credit ratings collateral posting requirements. If FPL's and NEECH's credit ratings were downgraded to BBB/Baa2 (a three level downgrade for FPL and a one level downgrade for NEECH from the current lowest applicable rating), applicable NEE subsidiaries would be required to post collateral such that the total posted collateral would be approximately $645 million (none at FPL) and $80 million (none at FPL) at December 31, 2021 and 2020, respectively. If FPL's and NEECH's credit ratings were downgraded to below investment grade, applicable NEE subsidiaries would be required to post additional collateral such that the total posted collateral would be approximately $2.7 billion ($35 million at FPL) and $1.2 billion ($75 million at FPL) at December 31, 2021 and 2020, respectively. Some derivative contracts do not contain credit ratings downgrade triggers, but do contain provisions that require certain financial measures be maintained and/or have credit-related cross-default triggers. In the event these provisions were triggered, applicable NEE subsidiaries could be required to post additional collateral of up to approximately $1,040 million ($145 million at FPL) and $880 million ($75 million at FPL) at December 31, 2021 and 2020, respectively.

Collateral related to derivatives may be posted in the form of cash or credit support in the normal course of business. At December 31, 2021 and 2020, applicable NEE subsidiaries have posted approximately $84 million (none at FPL) and $2 million (none at FPL), respectively, in cash and $1,060 million (none at FPL) and $66 million (none at FPL), respectively, in the form of letters of credit each of which could be applied toward the collateral requirements described above. FPL and NEECH have capacity under their credit facilities generally in excess of the collateral requirements described above that would be available to support, among other things, derivative activities. Under the terms of the credit facilities, maintenance of a specific credit rating is not a condition to drawing on these credit facilities, although there are other conditions to drawing on these credit facilities.

Additionally, some contracts contain certain adequate assurance provisions whereby a counterparty may demand additional collateral based on subjective events and/or conditions. Due to the subjective nature of these provisions, NEE and FPL are unable to determine an exact value for these items and they are not included in any of the quantitative disclosures above.

4. Non-Derivative Fair Value Measurements

Non-derivative fair value measurements consist of NEE’s and FPL’s cash equivalents and restricted cash equivalents, special use funds and other investments. The fair value of these financial assets is determined by using the valuation techniques and inputs as described in Note 3 – Fair Value Measurements of Derivative Instruments as well as below.

Cash Equivalents and Restricted Cash Equivalents – NEE and FPL hold investments in money market funds. The fair value of these funds is estimated using a market approach based on current observable market prices.

Special Use Funds and Other Investments – NEE and FPL hold primarily debt and equity securities directly, as well as indirectly through commingled funds. Substantially all directly held equity securities are valued at their quoted market prices. For directly held debt securities, multiple prices and price types are obtained from pricing vendors whenever possible, which enables cross-provider validations. A primary price source is identified based on asset type, class or issue of each security. Commingled funds, which are similar to mutual funds, are maintained by banks or investment companies and hold certain investments in accordance with a stated set of objectives. The fair value of commingled funds is primarily derived from the quoted prices in active markets of the underlying securities. Because the fund shares are offered to a limited group of investors, they are not considered to be traded in an active market.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Recurring Non-Derivative Fair Value Measurements – NEE's and FPL's financial assets and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows:

	December 31, 2021
	Level 1		Level 2			Level 3		Total
	(millions)
Assets:
Cash equivalents and restricted cash equivalents:(a)
NEE – equity securities	$	176	$	—		$	—	$	176
FPL – equity securities	$	58	$	—		$	—	$	58
Special use funds:(b)
NEE:
Equity securities	$	2,538	$	2,973	(c)	$	—	$	5,511
U.S. Government and municipal bonds	$	770	$	75		$	—	$	845
Corporate debt securities	$	7	$	955		$	—	$	962
Mortgage-backed securities	$	—	$	431		$	—	$	431
Other debt securities	$	2	$	265		$	—	$	267
FPL:
Equity securities	$	862	$	2,690	(c)	$	—	$	3,552
U.S. Government and municipal bonds	$	624	$	44		$	—	$	668
Corporate debt securities	$	6	$	720		$	—	$	726
Mortgage-backed securities	$	—	$	313		$	—	$	313
Other debt securities	$	2	$	225		$	—	$	227
Other investments:(d)
NEE:
Equity securities	$	70	$	2		$	—	$	72
Debt securities	$	111	$	162		$	12	$	285
FPL – equity securities	$	13	$	—		$	—	$	13

______________________

(a)Includes restricted cash equivalents of approximately $56 million ($53 million for FPL) in current other assets on the consolidated balance sheets.

(b)Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below.

(c)Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

(d)Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets.

	December 31, 2020
	Level 1		Level 2			Level 3		Total
	(millions)
Assets:
Cash equivalents and restricted cash equivalents:(a)
NEE – equity securities	$	742	$	—		$	—	$	742
FPL – equity securities	$	137	$	—		$	—	$	137
Special use funds:(b)
NEE:
Equity securities	$	2,237	$	2,489	(c)	$	—	$	4,726
U.S. Government and municipal bonds	$	590	$	127		$	—	$	717
Corporate debt securities	$	1	$	870		$	—	$	871
Mortgage-backed securities	$	—	$	422		$	—	$	422
Other debt securities	$	—	$	124		$	—	$	124
FPL:
Equity securities	$	752	$	2,260	(c)	$	—	$	3,012
U.S. Government and municipal bonds	$	449	$	87		$	—	$	536
Corporate debt securities	$	—	$	627		$	—	$	627
Mortgage-backed securities	$	—	$	335		$	—	$	335
Other debt securities	$	—	$	119		$	—	$	119
Other investments:(d)
NEE:
Equity securities	$	62	$	—		$	—	$	62
Debt securities	$	91	$	127		$	—	$	218
FPL - equity securities	$	12	$	—		$	—	$	12

______________________

(a)Includes restricted cash equivalents of approximately $111 million ($91 million for FPL) in current other assets and $42 million ($42 million for FPL) in noncurrent other assets on the consolidated balance sheets.

(b)Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below.

(c)Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

(d)Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Contingent Consideration – At December 31, 2021, NEER had approximately $261 million of contingent consideration liabilities which are included in noncurrent other liabilities on NEE's consolidated balance sheet. The liabilities relate to contingent consideration for the completion of capital expenditures for future development projects in connection with the acquisition of GridLiance Holdco, LP and GridLiance GP, LLC (see Note 6 – GridLiance). NEECH guarantees the contingent consideration obligations under the GridLiance acquisition agreements. Significant inputs and assumptions used in the fair value measurement, some of which are Level 3 and require judgement, include the projected timing and amount of future cash flows, estimated probability of completing future development projects as well as discount rates.

Fair Value of Financial Instruments Recorded at Other than Fair Value – The carrying amounts of commercial paper and other short-term debt approximate their fair values. The carrying amounts and estimated fair values of other financial instruments recorded at other than fair value are as follows:

	December 31, 2021					December 31, 2020
	Carrying Amount		Estimated Fair Value			Carrying Amount		Estimated Fair Value
	(millions)
NEE:
Special use funds(a)	$	906	$	907		$	919	$	920
Other investments(b)	$	102	$	102		$	29	$	29
Long-term debt, including current portion	$	52,745	$	57,290	(c)	$	46,082	$	51,525	(c)
FPL:
Special use funds(a)	$	672	$	672		$	718	$	719
Long-term debt, including current portion	$	18,510	$	21,379	(c)	$	17,236	$	21,178	(c)

______________________

(a)Primarily represents investments accounted for under the equity method and loans not measured at fair value on a recurring basis (Level 2).

(b)Included in noncurrent other assets on NEE's consolidated balance sheets.

(c)At December 31, 2021 and 2020, substantially all is Level 2 for NEE and FPL.

Special Use Funds – The special use funds noted above and those carried at fair value (see Recurring Non-Derivative Fair Value Measurements above) consist of NEE's nuclear decommissioning fund assets of approximately $8,846 million and $7,703 million at December 31, 2021 and 2020, respectively, ($6,082 million and $5,271 million, respectively, for FPL) and FPL's storm fund assets of $76 million and $76 million at December 31, 2021 and 2020, respectively. The investments held in the special use funds consist of equity and available for sale debt securities which are primarily carried at estimated fair value. The amortized cost of debt securities is approximately $2,438 million and $2,009 million at December 31, 2021 and 2020, respectively ($1,877 million and $1,521 million, respectively, for FPL). Debt securities included in the nuclear decommissioning funds have a weighted-average maturity at December 31, 2021 of approximately eight years at both NEE and FPL. FPL's storm fund primarily consists of debt securities with a weighted-average maturity at December 31, 2021 of approximately one year. The cost of securities sold is determined using the specific identification method.

Effective January 1, 2020, NEE and FPL adopted an accounting standards update that provides a modified version of the other-than-temporary impairment model for debt securities. The new available for sale debt security impairment model no longer allows consideration of the length of time during which the fair value has been less than its amortized cost basis when determining whether a credit loss exists. Credit losses are required to be presented as an allowance rather than as a write-down of securities not intended to be sold or required to be sold. NEE and FPL adopted this model prospectively. See Note 1 – Measurement of Credit Losses on Financial Instruments.

For FPL's special use funds, changes in fair value of debt and equity securities, including any estimated credit losses of debt securities, result in a corresponding adjustment to the related regulatory asset or liability accounts, consistent with regulatory treatment. For NEE's non-rate regulated operations, changes in fair value of debt securities result in a corresponding adjustment to 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. Changes in fair value of 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.

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NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Unrealized gains (losses) recognized on equity securities held at December 31, 2021, 2020 and 2019 are as follows:

	NEE						FPL
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
	(millions)
Unrealized gains	$	981	$	627	$	780	$	652	$	444	$	510

Realized gains and losses and proceeds from the sale or maturity of available for sale debt securities are as follows:

	NEE						FPL
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
	(millions)
Realized gains	$	78	$	110	$	68	$	59	$	83	$	44
Realized losses	$	73	$	70	$	48	$	57	$	56	$	29
Proceeds from sale or maturity of securities	$	1,831	$	2,541	$	3,005	$	1,330	$	2,162	$	2,539

The unrealized gains and unrealized losses on available for sale debt securities and the fair value of available for sale debt securities in an unrealized loss position are as follows:

	NEE				FPL
	December 31,				December 31,
	2021		2020		2021		2020
			(millions)
Unrealized gains	$	76	$	134	$	63	$	104
Unrealized losses(a)	$	19	$	9	$	15	$	9
Fair value	$	1,100	$	201	$	857	$	150

______________________

(a)Unrealized losses on available for sale debt securities in an unrealized loss position for greater than twelve months at December 31, 2021 and 2020 were not material to NEE or FPL.

Regulations issued by the FERC and the NRC provide general risk management guidelines to protect nuclear decommissioning funds and to allow such funds to earn a reasonable return. The FERC regulations prohibit, among other investments, investments in any securities of NEE or its subsidiaries, affiliates or associates, excluding investments tied to market indices or mutual funds. Similar restrictions applicable to the decommissioning funds for NEER's nuclear plants are included in the NRC operating licenses for those facilities or in NRC regulations applicable to NRC licensees not in cost-of-service environments. With respect to the decommissioning fund for Seabrook, decommissioning fund contributions and withdrawals are also regulated by the NDFC pursuant to New Hampshire law.

The nuclear decommissioning reserve funds are managed by investment managers who must comply with the guidelines of NEE and FPL and the rules of the applicable regulatory authorities. The funds' assets are invested giving consideration to taxes, liquidity, risk, diversification and other prudent investment objectives.

Nonrecurring Fair Value Measurements – NEE tests its equity method investments for impairment whenever events or changes in circumstances indicate that the investment may be impaired. During the preparation of NEE's December 31, 2020 financial statements, it was determined that NextEra Energy Resources' investment in Mountain Valley Pipeline, LLC (Mountain Valley Pipeline) accounted for under the equity method of accounting was other-than-temporarily impaired. The impairment is the result of continued legal and regulatory challenges that have resulted in substantial delays in achieving commercial operation and increased costs to complete construction. More specifically at the end of 2020 and into early 2021, developments in the legal, regulatory and political environment caused NextEra Energy Resources to consider the investment impaired and the impairment to be other than temporary. The challenges included legal challenges to the various permits needed to complete construction and the regulatory approvals received, regulatory challenges related to alternative construction plans and the extended construction period, and the political and environmental challenges with the construction of an interstate pipeline. Accordingly, NextEra Energy Resources performed a fair value analysis based on the market approach to determine the amount of the impairment. The challenges to complete construction and the resulting economic outlook for the pipeline were considered in determining the magnitude of the other-than-temporary impairment. Based on the fair value analysis, the equity method investment with a carrying amount of approximately $1.9 billion was written down to its estimated fair value of approximately $400 million as of December 31, 2020, resulting in an impairment charge of $1.5 billion (or $1.2 billion after tax), which is recorded in equity in

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

earnings (losses) of equity method investees in NEE’s consolidated statements of income for the year ended December 31, 2020.

The fair value estimate was based on a probability-weighted earnings before interest, taxes, depreciation and amortization (EBITDA) multiple valuation technique using a market participant view of the potential different outcomes for the investment. As part of the valuation, NextEra Energy Resources used observable inputs where available, including the EBITDA multiples of recent pipeline transactions. Significant unobservable inputs (Level 3), including the probabilities assigned to the different potential outcomes, the forecasts of operating revenues and costs, and the projected capital expenditures to complete the project, were also used in the estimation of fair value. An increase in the revenue forecasts, a decrease in the projected operating or capital expenditures or an increase in the probability assigned to the full pipeline being completed would result in an increased fair market value. Changes in the opposite direction of those unobservable inputs would result in a decreased fair market value.

On February 2, 2022, the U.S. Court of Appeals for the Fourth Circuit (the 4th Circuit) vacated and remanded Mountain Valley Pipeline’s Biological Opinion issued by the U.S. Fish and Wildlife Service. While NextEra Energy Resources continues to evaluate options and next steps with its joint venture partners, this event along with the 4th Circuit vacatur and remand of the U.S. Forest Service right-of-way grant on January 25, 2022 caused NextEra Energy Resources to re-evaluate its investment in Mountain Valley Pipeline for further other-than-temporary impairment, which evaluation coincided with the preparation of NEE's December 31, 2021 financial statements. As a result of this evaluation, it was determined that the continued legal and regulatory challenges have resulted in a very low probability of pipeline completion. Accordingly, NextEra Energy Resources updated its fair value estimate using the same probability-weighted EBITDA multiple valuation technique using a market participant view of the potential different outcomes for the investment as discussed above. Based on this fair value analysis, NextEra Energy Resources recorded an impairment charge in the first quarter of 2022 of approximately $0.8 billion ($0.6 billion after tax). This impairment charge resulted in the complete write off of NextEra Energy Resources’ equity method investment carrying amount of approximately $0.6 billion, as well as the recording of a liability of approximately $0.2 billion which reflects NextEra Energy Resources’ share of estimated future ARO costs.

5. Income Taxes

The components of income taxes are as follows:

	NEE						FPL
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
	(millions)
Federal:
Current	$	(26)	$	105	$	167	$	85	$	16	$	390
Deferred	311		(148)		115		545		474		(41)
Total federal	285		(43)		282		630		490		349
State:
Current	(62)		18		23		1		32		50
Deferred	125		69		143		207		156		85
Total state	63		87		166		208		188		135
Total income taxes	$	348	$	44	$	448	$	838	$	678	$	484

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NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

A reconciliation between the effective income tax rates and the applicable statutory rate is as follows:

	NEE						FPL
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%
Increases (reductions) resulting from:
State income taxes – net of federal income tax benefit(a)	1.6		2.8		3.4		4.1		4.2		3.5
Taxes attributable to noncontrolling interests	5.0		4.8		2.1		—		—		—
PTCs and ITCs – NEER	(10.3)		(11.8)		(7.2)		—		—		—
Amortization of deferred regulatory credit(b)	(4.4)		(7.2)		(6.2)		(3.5)		(4.9)		(8.0)
Foreign operations(c)	0.2		(2.4)		—		—		—		—
Other – net	(2.1)		(5.4)		(1.4)		(0.9)		(1.3)		(0.4)
Effective income tax rate	11.0	%	1.8	%	11.7	%	20.7	%	19.0	%	16.1	%

_________________________

(a)NEE's 2019 amount reflects a valuation allowance of approximately $48 million related to deferred state tax credits.

(b)2019 reflects an adjustment of approximately $83 million recorded by FPL to reduce income tax expense for the cumulative amortization of excess deferred income taxes from January 1, 2018 as a result of the FPSC's order in connection with its review of impacts associated with the Tax Cuts and Jobs Act. One of the provisions of the order requires FPL to amortize approximately $870 million of its excess deferred income taxes over a period not to exceed ten years.

(c)The 2020 gain on sale of the Spain solar projects was not taxable for federal and state income tax purposes (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests).

The income tax effects of temporary differences giving rise to consolidated deferred income tax liabilities and assets are as follows:

	NEE				FPL
	December 31,				December 31,
	2021		2020		2021		2020
	(millions)
Deferred tax liabilities:
Property-related	$	10,018	$	10,065	$	7,831	$	7,548
Pension	564		437		425		394
Investments in partnerships and joint ventures	2,783		2,238		3		3
Other	2,092		1,730		1,232		862
Total deferred tax liabilities	15,457		14,470		9,491		8,807
Deferred tax assets and valuation allowance:
Decommissioning reserves	296		290		296		290
Net operating loss carryforwards	330		299		2		3
Tax credit carryforwards	4,646		3,859		182		4
ARO and accrued asset removal costs	199		347		126		272
Regulatory liabilities	1,421		1,380		1,397		1,356
Other	733		755		351		363
Valuation allowance(a)	(282)		(289)		—		—
Net deferred tax assets	7,343		6,641		2,354		2,288
Net deferred income taxes	$	8,114	$	7,829	$	7,137	$	6,519

______________________

(a)Reflects valuation allowances related to deferred state tax credits and state operating loss carryforwards.

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Deferred tax assets and liabilities are included on the consolidated balance sheets as follows:

	NEE				FPL
	December 31,				December 31,
	2021		2020		2021		2020
			(millions)
Noncurrent other assets	$	196	$	191	$	—	$	—
Deferred income taxes – noncurrent liabilities	(8,310)		(8,020)		(7,137)		(6,519)
Net deferred income taxes	$	(8,114)	$	(7,829)	$	(7,137)	$	(6,519)

The components of NEE's deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2021 are as follows:

	Amount			Expiration Dates
	(millions)
Net operating loss carryforwards:
Federal	$	51	(a)	2034 – 2038
State	264			2022 – 2041
Foreign	15			2022 – 2041
Net operating loss carryforwards	$	330
Tax credit carryforwards:
Federal	$	4,296		2030 – 2041
State	345		(b)	2022 – 2046
Foreign	5			2035 – 2041
Tax credit carryforwards	$	4,646

______________________

(a)Includes $49 million of net operating loss carryforwards with an indefinite expiration period.

(b)Includes $191 million of ITC carryforwards with an indefinite expiration period.

6. Acquisitions

Gulf Power Company – On January 1, 2019, NEE acquired the outstanding common shares of Gulf Power Company, a rate-regulated electric utility under the jurisdiction of the FPSC, which served approximately 470,000 customers in eight counties throughout northwest Florida, had approximately 9,500 miles of transmission and distribution lines and owned approximately 2,300 MW of net generating capacity. The purchase price included approximately $4.44 billion in cash consideration and the assumption of approximately $1.3 billion of Gulf Power debt.

Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed on January 1, 2019 based on their fair value. The approval by the FPSC of Gulf Power's rates, which were intended to allow Gulf Power to collect from retail customers total revenues equal to Gulf Power's costs of providing service, including a reasonable rate of return on invested capital, was considered a fundamental input in measuring the fair value of Gulf Power's assets and liabilities and, as such, NEE concluded that the carrying values of all assets and liabilities recoverable through rates were representative of their fair values. As a result, NEE acquired assets of approximately $5.2 billion, primarily relating to property, plant and equipment of $4.0 billion and regulatory assets of $494 million, and assumed liabilities of approximately $3.4 billion, including $1.3 billion of long-term debt, $635 million of regulatory liabilities and $562 million of deferred income taxes. The excess of the purchase price over the fair value of assets acquired and liabilities assumed resulted in approximately $2.7 billion of goodwill which had been recognized on NEE's consolidated balance sheet. The goodwill arising from the transaction represents expected benefits from continued expansion of NEE's regulated businesses and the indefinite life of Gulf Power's service area franchise.

Merger of FPL and Gulf Power Company – 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 16. 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 Note 1 – Rate Regulation – Base Rates Effective January 2022 through December 2025. As a result of the merger, FPL acquired assets of approximately $6.7 billion, primarily relating to property, plant and equipment, net of approximately $4.9 billion and regulatory assets of $1.2 billion, and assumed liabilities of approximately $3.9 billion, including $1.8 billion of debt, primarily long-term debt, $729 million of deferred income taxes and $566 million of regulatory liabilities. Additionally, goodwill of approximately $2.7 billion and purchase accounting adjustments associated with the 2019 Gulf Power Company acquisition by NEE were transferred to FPL from Corporate and

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Other at NEE. Goodwill associated with the Gulf Power Company acquisition is reflected within Corporate and Other at FPL and, for impairment testing, is included in the Gulf Power reporting unit. The assets acquired and liabilities assumed by FPL were at carrying amounts as the merger was between entities under common control.

Trans Bay Cable LLC – On July 16, 2019, a wholly owned subsidiary of NEET acquired the membership interests of Trans Bay Cable LLC (Trans Bay), which owns and operates a 53-mile, high-voltage direct current underwater transmission cable system in California extending from Pittsburg to San Francisco, with utility rates set by the FERC and revenues paid by the California Independent System Operator. The purchase price included approximately $670 million in cash consideration and the assumption of debt of approximately $422 million.

Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed based on their fair value. The approval by the FERC of Trans Bay’s rates, which is intended to allow Trans Bay to collect total revenues equal to Trans Bay's costs for the development, financing, construction, operation and maintenance of Trans Bay, including a reasonable rate of return on invested capital, is considered a fundamental input in measuring the fair value of Trans Bay's assets and liabilities and, as such, NEE concluded that the carrying values of all assets and liabilities recoverable through rates are representative of their fair values. As a result, NEE acquired assets of approximately $703 million, primarily relating to property, plant and equipment, and assumed liabilities of approximately $643 million, primarily relating to long-term debt. The excess of the purchase price over the fair value of assets acquired and liabilities assumed resulted in approximately $610 million of goodwill which has been recognized on NEE's consolidated balance sheet, of which approximately $572 million is expected to be deductible for tax purposes. Goodwill associated with the Trans Bay acquisition is reflected within NEER and, for impairment testing, is included in the rate-regulated transmission reporting unit. The goodwill arising from the transaction represents expected benefits from continued expansion of NEE's regulated businesses.

GridLiance – On March 31, 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 with approximately 700 miles of high-voltage transmission lines across six states, five in the Midwest and Nevada. The purchase price included approximately $502 million in cash consideration, and the assumption of approximately $175 million of debt, excluding post-closing adjustments.

Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed based on their fair value. The approval by the FERC of GridLiance's rates, which is intended to allow GridLiance to collect total revenues equal to GridLiance's costs for the development, financing, construction, operation and maintenance of GridLiance, including a reasonable rate of return on invested capital, is considered a fundamental input in measuring the fair value of GridLiance's assets and liabilities and, as such, NEE concluded that the carrying values of all assets and liabilities recoverable through rates are representative of their fair values. As a result, NEE acquired assets of approximately $384 million, primarily relating to property, plant and equipment, and assumed liabilities of approximately $210 million, primarily relating to long-term debt. The acquisition agreements are subject to earn-out provisions for additional payments, valued at approximately $264 million at March 31, 2021, to be made upon the completion of capital expenditures for future development projects (see Note 4 – Contingent Consideration). The excess of the purchase price over the fair value of assets acquired and liabilities assumed resulted in approximately $592 million of goodwill which has been recognized on NEE's consolidated balance sheet at December 31, 2021, of which approximately $586 million is expected to be deductible for tax purposes. Goodwill associated with the GridLiance acquisition is reflected within NEER and, for impairment testing, is included in the rate-regulated transmission reporting unit. The goodwill arising from the transaction represents expected benefits from continued expansion of NEE's regulated businesses. The valuation of the acquired net assets is subject to change as additional information related to the estimates is obtained during the measurement period.

7. Property, Plant and Equipment

Property, plant and equipment consists of the following at December 31:

	NEE				FPL
	2021		2020		2021		2020
	(millions)
Electric plant in service and other property	$	112,500	$	105,860	$	67,771	$	62,963
Nuclear fuel	1,606		1,604		1,170		1,143
Construction work in progress	14,141		10,639		6,326		5,361
Property, plant and equipment, gross	128,247		118,103		75,267		69,467
Accumulated depreciation and amortization	(28,899)		(26,300)		(17,040)		(15,588)
Property, plant and equipment – net	$	99,348	$	91,803	$	58,227	$	53,879

FPL – At December 31, 2021, FPL's gross investment in electric plant in service and other property for the electric generation, transmission, distribution and general facilities of FPL represented approximately 46%, 13%, 35% and 6%, respectively; the

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respective amounts at December 31, 2020 were 47%, 12%, 35% and 6%. Substantially all of FPL's properties are subject to the lien of FPL's mortgage, which secures most debt securities issued by FPL. The weighted annual composite depreciation and amortization rate for FPL's electric plant in service, including capitalized software, but excluding the effects of decommissioning, dismantlement and the depreciation adjustments discussed in the following sentence, was approximately 3.8%, 3.8% and 3.9% for 2021, 2020 and 2019, respectively. In accordance with the 2016 rate agreement (see Note 1 – Rate Regulation – Base Rates Effective January 2017 through December 2021), FPL recorded reserve amortization (reversal) of approximately $429 million, $(1) million and $(357) million in 2021, 2020 and 2019, respectively. During each of 2021, 2020 and 2019, the FPL segment capitalized AFUDC at a rate of 6.22%, which amounted to approximately $124 million, $79 million and $80 million, respectively. During each of 2021, 2020 and 2019, Gulf Power capitalized AFUDC at a rate of 5.73%, which amounted to approximately $53 million, $38 million and $6 million, respectively.

NEER – At December 31, 2021, wind, solar and nuclear plants represented approximately 53%, 14% and 8%, respectively, of NEER's depreciable electric plant in service and other property; the respective amounts at December 31, 2020 were 55%, 13% and 8%. The estimated useful lives of NEER's plants range primarily from 30 to 35 years for wind plants, 30 to 35 years for solar plants and 23 to 47 years for nuclear plants. NEER's oil and gas production assets represented approximately 14% and 14% of NEER's depreciable electric plant in service and other property at December 31, 2021 and 2020, respectively. A number of NEER's generation, regulated transmission and pipeline facilities are encumbered by liens securing various financings. The net book value of NEER's assets serving as collateral was approximately $13.5 billion at December 31, 2021. Interest capitalized on construction projects amounted to approximately $139 million, $168 million and $135 million during 2021, 2020 and 2019, respectively.

Jointly-Owned Electric Plants – Certain NEE subsidiaries own undivided interests in the jointly-owned facilities described below, and are entitled to a proportionate share of the output from those facilities. The subsidiaries are responsible for their share of the operating costs, as well as providing their own financing. Accordingly, each subsidiary's proportionate share of the facilities and related revenues and expenses is included in the appropriate balance sheet and statement of income captions. NEE's and FPL's respective shares of direct expenses for these facilities are included in fuel, purchased power and interchange expense, O&M expenses, depreciation and amortization expense and taxes other than income taxes and other – net in NEE's and FPL's consolidated statements of income.

NEE's and FPL's proportionate ownership interest in jointly-owned facilities is as follows:

	December 31, 2021
	Ownership Interest		Gross Investment(a)		Accumulated Depreciation(a)		Construction Work in Progress
			(millions)
FPL:
St. Lucie Unit No. 2	85	%	$	2,284	$	1,044	$	90
Daniel Units Nos. 1 and 2(b)	50	%	$	759	$	274	$	16
Scherer Unit No. 3(c)	25	%	$	449	$	204	$	3
NEER:
Seabrook	88.23	%	$	1,330	$	453	$	58
Wyman Station Unit No. 4	91.19	%	$	30	$	11	$	—
Stanton	65	%	$	139	$	19	$	—
Transmission substation assets located in Seabrook, New Hampshire	88.23	%	$	114	$	8	$	22

______________________

(a)Excludes nuclear fuel.

(b)FPL intends to retire its share of these units in 2024. Net book value is reflected in other property on NEE's and FPL's consolidated balance sheets.

(c)Together with its joint interest owner, FPL intends to retire this unit in 2028. Net book value is reflected in other property on NEE's and FPL's consolidated balance sheets.

8. Equity Method Investments

At December 31, 2021 and 2020, NEE's equity method investments totaled approximately $6,159 million and $5,728 million, respectively. The principal entities included in investment in equity method investees on NEE's consolidated balance sheets are NEP OpCo, Sabal Trail Transmission, LLC (Sabal Trail) (see Note 15 – Contracts), Mountain Valley Pipeline (see Note 15 – Contracts), and Silver State South Solar, LLC. NEE's interest in these entities range from approximately 32% to 55%, and these entities own or are constructing natural gas pipelines or own electric generation facilities.

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Summarized combined information for these principal entities is as follows:

	2021		2020
	(millions)
Operating revenue	$	1,469	$	1,359
Operating income	$	559	$	538
Net income	$	739	$	516
Total assets	$	29,537	$	22,717
Total liabilities	$	9,501	$	6,612
Partners'/members' equity(a)	$	20,036	$	16,105
NEE's share of underlying equity in the principal entities	$	4,352	$	3,927
Difference between investment carrying amount and underlying equity in net assets(b)	1,133		1,312
NEE's investment carrying amount for the principal entities	$	5,485	$	5,239

______________________

(a)Reflects NEE's interest, as well as third-party interests, in NEP OpCo.

(b)Approximately $2.6 billion in 2021 and $2.8 billion in 2020 is associated with NEP OpCo, of which approximately 75% and 70%, respectively, relates to goodwill and is not being amortized and the remaining balance is being amortized primarily over a period of 17 to 25 years. The difference for both years is net of an approximately $1.5 billion impairment charge in 2020 related to NextEra Energy Resources' investment in Mountain Valley Pipeline. In the first quarter of 2022, NextEra Energy Resources recorded an additional impairment charge to completely write off its investment in Mountain Valley Pipeline. See Note 4 – Nonrecurring Fair Value Measurements for a discussion of the impairment charges.

NextEra Energy Resources provides operational, management and administrative services as well as transportation and fuel management services to NEP and its subsidiaries under various agreements (service agreements). NextEra Energy Resources is also party to a cash sweep and credit support (CSCS) agreement with a subsidiary of NEP. At December 31, 2021 and 2020, the cash sweep amounts (due to NEP and its subsidiaries) held in accounts belonging to NextEra Energy Resources or its subsidiaries were approximately $57 million and $10 million, respectively, and are included in accounts payable. Fee income related to the CSCS agreement and the service agreements totaled approximately $148 million, $120 million and $101 million for the years ended December 31, 2021, 2020 and 2019, respectively, and is included in operating revenues in NEE's consolidated statements of income. Amounts due from NEP of approximately $113 million and $68 million are included in other receivables and $40 million and $32 million are included in noncurrent other assets at December 31, 2021 and 2020, respectively. See also Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests for amounts due to NEP for reimbursement of construction-related costs. NEECH or NextEra Energy Resources guaranteed or provided indemnifications, letters of credit or surety bonds totaling approximately $3,778 million at December 31, 2021 primarily related to obligations on behalf of NEP's subsidiaries with maturity dates ranging from 2022 to 2059, including certain project performance obligations, obligations under financing and interconnection agreements and obligations, primarily incurred and future construction payables, associated with the December 2021 sale of projects to NEP (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests). Payment guarantees and related contracts with respect to unconsolidated entities for which NEE or one of its subsidiaries are the guarantor are recorded on NEE’s consolidated balance sheets at fair value. At December 31, 2021, approximately $41 million related to the fair value of the credit support provided under the CSCS agreement is recorded as noncurrent other liabilities on NEE's consolidated balance sheet.

9. Variable Interest Entities (VIEs)

NEER – At December 31, 2021, NEE consolidates a number of VIEs within the NEER segment. Subsidiaries within the NEER segment are considered the primary beneficiary of these VIEs since they control the most significant activities of these VIEs, including operations and maintenance, and they have the obligation to absorb expected losses of these VIEs.

Eight indirect subsidiaries of NextEra Energy Resources have an ownership interest ranging from approximately 50% to 67% in entities which own and operate solar facilities with the capability of producing a total of approximately 772 MW. Each of the subsidiaries is considered a VIE since the non-managing members have no substantive rights over the managing members, and is consolidated by NextEra Energy Resources. These entities sell their electric output to third parties under power sales contracts with expiration dates ranging from 2035 through 2052. These entities have third-party debt which is secured by liens against the assets of the entities. The debt holders have no recourse to the general credit of NextEra Energy Resources for the repayment of debt. The assets and liabilities of these VIEs were approximately $1,851 million and $1,258 million, respectively, at December 31, 2021. There were three of these consolidated VIEs at December 31, 2020, and the assets and liabilities of those VIEs at such date totaled approximately $751 million and $607 million, respectively. At December 31, 2021 and 2020, the assets and liabilities of these VIEs consisted primarily of property, plant and equipment and long-term debt.

NEE consolidates a NEET VIE that is constructing an approximately 280-mile electricity transmission line. A NEET subsidiary is the primary beneficiary and controls the most significant activities during the construction period, including controlling the construction budget. NEET is entitled to receive 50% of the profits and losses of the entity. The assets and liabilities of the VIE totaled approximately $614 million and $64 million, respectively, at December 31, 2021, and $423 million and $68 million,

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respectively, at December 31, 2020. At December 31, 2021 and 2020, the assets and liabilities of this VIE consisted primarily of property, plant and equipment and accounts payable.

NextEra Energy Resources consolidates a VIE which has a 10% direct ownership interest in wind generation facilities and solar facilities which have the capability of producing approximately 400 MW and 599 MW, respectively. These entities sell their electric output under power sales contracts to third parties with expiration dates ranging from 2025 through 2040. These entities are also considered a VIE because the holders of differential membership interests in these entities do not have substantive rights over the significant activities of these entities. The assets and liabilities of the VIE were approximately $1,518 million and $79 million, respectively, at December 31, 2021, and $1,572 million and $393 million, respectively, at December 31, 2020. At December 31, 2021 and 2020, the assets and liabilities of this VIE consisted primarily of property, plant and equipment and accounts payable.

The other 33 NextEra Energy Resources VIEs that are consolidated primarily relate to certain subsidiaries which have sold differential membership interests in entities which own and operate wind generation as well as solar and solar plus battery storage facilities with the capability of producing a total of approximately 10,626 MW and 890 MW, respectively, and own wind generation as well as solar and solar plus battery storage facilities that, upon completion of construction, which is anticipated in the first half of 2022, are expected to have a total capacity of approximately 200 MW and 625 MW, respectively. These entities sell, or will sell, their electric output either under power sales contracts to third parties with expiration dates ranging from 2024 through 2053 or in the spot market. These entities are considered VIEs because the holders of differential membership interests do not have substantive rights over the significant activities of these entities. NextEra Energy Resources has financing obligations with respect to these entities, including third-party debt which is secured by liens against the generation facilities and the other assets of these entities or by pledges of NextEra Energy Resources' ownership interest in these entities. The debt holders have no recourse to the general credit of NEER for the repayment of debt. The assets and liabilities of these VIEs totaled approximately $17,419 million and $1,480 million, respectively, at December 31, 2021, and $16,180 million and $1,741 million, respectively at December 31, 2020. At December 31, 2021 and 2020, the assets and liabilities of these VIEs consisted primarily of property, plant and equipment and accounts payable. At December 31, 2021, subsidiaries of NEE had guarantees related to certain obligations of two of these consolidated VIEs.

Other – At December 31, 2021 and 2020, several NEE subsidiaries had investments totaling approximately $4,559 million ($3,799 million at FPL) and $3,704 million ($3,124 million at FPL), respectively, which are included in special use funds and noncurrent other assets on NEE's consolidated balance sheets and in special use funds on FPL's consolidated balance sheets. These investments represented primarily commingled funds and mortgage-backed securities. NEE subsidiaries, including FPL, are not the primary beneficiaries and therefore do not consolidate any of these entities because they do not control any of the ongoing activities of these entities, were not involved in the initial design of these entities and do not have a controlling financial interest in these entities.

Certain subsidiaries of NEE have noncontrolling interests in entities accounted for under the equity method, including NEE's noncontrolling interest in NEP OpCo (see Note 8). These entities are limited partnerships or similar entity structures in which the limited partners or non-managing members do not have substantive rights over the significant activities of these entities, and therefore are considered VIEs. NEE is not the primary beneficiary because it does not have a controlling financial interest in these entities, and therefore does not consolidate any of these entities. NEE’s investment in these entities totaled approximately $4,214 million and $3,932 million at December 31, 2021 and 2020, respectively. At December 31, 2021, subsidiaries of NEE had guarantees related to certain obligations of one of these entities, as well as commitments to invest an additional approximately $110 million in several of these entities. See further discussion of such guarantees and commitments in Note 15 – Commitments and – Contracts, respectively.

10. Leases

NEE has operating and finance leases primarily related to purchased power agreements, land use agreements that convey exclusive use of the land during the arrangement for certain of its renewable energy projects and substations, buildings and equipment. Operating and finance leases primarily have fixed payments with expected expiration dates ranging from 2022 to 2083, with the exception of operating leases related to three land use agreements with an expiration date of 2106, some of which include options to extend the leases up to 20 years and some have options to terminate at NEE's discretion. At December 31, 2021, NEE’s ROU assets and lease liabilities for operating leases totaled approximately $547 million and $555 million, respectively; the respective amounts at December 31, 2020 were $535 million and $541 million. At December 31, 2021, NEE’s ROU assets and lease liabilities for finance leases totaled approximately $205 million and $200 million, respectively; the respective amounts at December 31, 2020 were $128 million and $124 million. NEE’s lease liabilities at December 31, 2021 and 2020 were calculated using a weighted-average incremental borrowing rate at the lease inception of 3.57% and 3.81%, respectively, for operating leases and 3.52% and 3.50%, respectively, for finance leases, and a weighted-average remaining lease term of 39 years and 33 years, respectively, for operating leases and 31 years and 25 years, respectively, for finance leases. At December 31, 2021, expected lease payments over the remaining terms of the leases were approximately $1.4 billion with no one year being material. NEE's operating lease cost for the years ended December 31, 2021, 2020 and 2019 totaled approximately $92 million, $95 million and $91 million, respectively. During the year ended December 31, 2021, 2020 and 2019,

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NEE's ROU assets obtained in exchange for operating lease obligations totaled approximately $92 million, $121 million and $450 million, respectively, and in 2019 primarily relate to leases acquired with the Gulf Power ($262 million at FPL) and Trans Bay acquisitions (see Note 6). Other operating and finance lease-related amounts were not material to NEE's consolidated statements of income for the periods presented.

NEE has operating and sales-type leases primarily related to a natural gas and oil electric generation facility and certain battery storage facilities that sell their electric output under power sales agreements to third parties which provide the customers the ability to dispatch the facilities. At December 31, 2021 and 2020, NEE recorded a net investment in sales-type leases of approximately $42 million and $47 million, respectively. At December 31, 2021, the power sales agreements have expiration dates from 2024 to 2043 and NEE expects to receive approximately $843 million of lease payments over the remaining terms of the power sales agreements with no one year being material. Operating and sales-type lease-related amounts were not material to NEE's consolidated statements of income for the periods presented.

11. Asset Retirement Obligations

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. For NEE's rate-regulated operations, including FPL, the accounting provisions result in timing differences in the recognition of legal asset retirement costs for financial reporting purposes and the method the regulator allows for recovery in rates. See Note 1 – Rate Regulation and – Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs.

A rollforward of NEE's and FPL's AROs is as follows:

	NEE			FPL
	(millions)
Balances, December 31, 2019	$	3,506		$	2,410
Liabilities incurred	138			—
Accretion expense	169			103
Liabilities settled	(53)			(32)
Revision in estimated cash flows – net	(594)		(a)	(545)		(a)
Balances, December 31, 2020	3,166		(b)	1,936		(b)
Liabilities incurred	79			7
Accretion expense	141			78
Liabilities settled	(88)		(c)	(15)
Revision in estimated cash flows – net	(119)		(d)	101		(e)
Balances, December 31, 2021	$	3,179	(b)	$	2,107	(b)

______________________

(a)Primarily reflects the effect of revised cost estimates for decommissioning FPL's nuclear units consistent with the updated nuclear decommissioning studies filed with the FPSC in December 2020.

(b)Includes the current portion of AROs as of December 31, 2021 and 2020 of approximately $97 million ($58 million for FPL) and $109 million ($65 million for FPL), respectively, which are included in other current liabilities on NEE's and FPL's consolidated balance sheets.

(c)Includes approximately $35 million related to project sales to NEP as well as other sales of businesses and assets. See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

(d)The increase at FPL discussed in (e) was offset primarily by the effect of revised cost estimates and useful lives of NEER's solar facilities.

(e)Primarily reflects the effect of pending license extension requests of St. Lucie Units Nos. 1 and 2 for an additional 20 years.

Restricted funds for the payment of future expenditures to decommission NEE's and FPL's nuclear units included in special use funds on NEE's and FPL's consolidated balance sheets are presented below (see Note 4 – Special Use Funds). Duane Arnold is being actively decommissioned and was granted an exemption from the NRC, which allows for use of the funds for certain other site restoration activities in addition to decommissioning obligations recorded as AROs.

	NEE		FPL
	(millions)
Balances, December 31, 2021	$	8,846	$	6,082
Balances, December 31, 2020	$	7,703	$	5,271

NEE and FPL have identified but not recognized ARO liabilities related to the majority of their electric transmission and distribution assets and pipelines resulting from easements over property not owned by NEE or FPL. These easements are generally perpetual and only require retirement action upon abandonment or cessation of use of the property or facility for its specified purpose. The related ARO liability is not estimable for such easements as NEE and FPL intend to use these properties indefinitely. In the event NEE or FPL decide to abandon or cease the use of a particular easement, an ARO liability would be recorded at that time.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

12. Employee Retirement Benefits

Employee Pension Plan and Other Benefits Plans – NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries. NEE also has a supplemental executive retirement plan (SERP), which includes a non-qualified supplemental defined benefit pension component that provides benefits to a select group of management and highly compensated employees, and sponsors a contributory postretirement plan for other benefits for retirees of NEE and its subsidiaries meeting certain eligibility requirements. The total accrued benefit cost of the SERP and postretirement plans is approximately $300 million ($139 million for FPL) and $323 million ($156 million for FPL) at December 31, 2021 and 2020, respectively.

Pension Plan Assets, Benefit Obligations and Funded Status – The changes in assets, benefit obligations and the funded status of the pension plan are as follows:

	2021		2020
	(millions)
Change in pension plan assets:
Fair value of plan assets at January 1	$	5,314	$	4,800
Actual return on plan assets	627		723
Benefit payments	(253)		(209)
Fair value of plan assets at December 31	$	5,688	$	5,314
Change in pension benefit obligation:
Obligation at January 1	$	3,607	$	3,363
Service cost	90		85
Interest cost	64		92
Special termination benefit(a)	—		16
Plan amendments	—		1
Actuarial losses (gains) – net	(63)		259
Benefit payments	(253)		(209)
Obligation at December 31(b)	$	3,445	$	3,607
Funded status:
Prepaid pension benefit costs at NEE at December 31	$	2,243	$	1,707
Prepaid pension benefit costs at FPL at December 31(c)	$	1,657	$	1,550

_________________________

(a)Reflects enhanced early retirement benefit.

(b)NEE's accumulated pension benefit obligation, which includes no assumption about future salary levels, at December 31, 2021 and 2020 was approximately $3,352 million and $3,521 million, respectively.

(c)Reflects FPL's allocated benefits under NEE's pension plan.

NEE's unrecognized amounts included in accumulated other comprehensive income (loss) yet to be recognized as components of prepaid pension benefit costs are as follows:

	2021		2020
	(millions)
Unrecognized prior service benefit (net of $1 tax expense and $1 tax expense, respectively)	$	2	$	2
Unrecognized gains (losses) (net of $7 tax expense and $24 tax benefit, respectively)	41		(60)
Total	$	43	$	(58)

NEE's unrecognized amounts included in regulatory assets (liabilities) yet to be recognized as components of net prepaid pension benefit costs are as follows:

	2021		2020
	(millions)
Unrecognized prior service benefit	$	(1)	$	(1)
Unrecognized losses (gains)	(80)		163
Total	$	(81)	$	162

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The following table provides the assumptions used to determine the benefit obligation for the pension plan. These rates are used in determining net periodic pension income in the following year.

	2021		2020
Discount rate(a)	2.87	%	2.53	%
Salary increase	4.90	%	4.40	%
Weighted-average interest crediting rate	3.79	%	3.82	%

_________________________

(a)The method of estimating the interest cost component of net periodic benefit costs uses a full yield curve approach by applying a specific spot rate along the yield curve.

NEE's investment policy for the pension plan recognizes the benefit of protecting the plan's funded status, thereby avoiding the necessity of future employer contributions. Its broad objectives are to achieve a high rate of total return with a prudent level of risk taking while maintaining sufficient liquidity and diversification to avoid large losses and preserve capital over the long term.

The NEE pension plan fund's current target asset allocation, which is expected to be reached over time, is 45% equity investments, 32% fixed income investments, 13% alternative investments and 10% convertible securities. The pension fund's investment strategy emphasizes traditional investments, broadly diversified across the global equity and fixed income markets, using a combination of different investment styles and vehicles. The pension fund's equity and fixed income holdings consist of both directly held securities as well as commingled investment arrangements such as common and collective trusts, pooled separate accounts, registered investment companies and limited partnerships. The pension fund's convertible security assets are principally direct holdings of convertible securities and include a convertible security oriented limited partnership. The pension fund's alternative investments consist primarily of private equity and real estate oriented investments in limited partnerships as well as absolute return oriented limited partnerships that use a broad range of investment strategies on a global basis.

The fair value measurements of NEE's pension plan assets by fair value hierarchy level are as follows:

	December 31, 2021(a)
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(millions)
Equity securities(b)	$	1,977	$	29	$	2	$	2,008
Equity commingled vehicles(c)	—		889		—		889
U.S. Government and municipal bonds	131		6		—		137
Corporate debt securities(d)	—		351		—		351
Asset-backed securities	—		386		—		386
Debt security commingled vehicles(e)	—		219		—		219
Convertible securities(f)	91		489		—		580
Total investments in the fair value hierarchy	$	2,199	$	2,369	$	2	4,570
Total investments measured at net asset value(g)							1,118
Total fair value of plan assets							$	5,688

_____________________

(a)See Notes 3 and 4 for discussion of fair value measurement techniques and inputs.

(b)Includes foreign investments of $927 million.

(c)Includes foreign investments of $169 million.

(d)Includes foreign investments of $109 million.

(e)Includes foreign investments of $5 million.

(f)Includes foreign investments of $41 million.

(g)Includes foreign investments of $220 million.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	December 31, 2020(a)
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(millions)
Equity securities(b)	$	2,017	$	10	$	3	$	2,030
Equity commingled vehicles(c)	—		668		—		668
U.S. Government and municipal bonds	169		8		—		177
Corporate debt securities(d)	—		340		—		340
Asset-backed securities	—		375		—		375
Debt security commingled vehicles(e)	—		201		—		201
Convertible securities(f)	64		453		—		517
Total investments in the fair value hierarchy	$	2,250	$	2,055	$	3	4,308
Total investments measured at net asset value(g)							1,006
Total fair value of plan assets							$	5,314

______________________

(a)See Notes 3 and 4 for discussion of fair value measurement techniques and inputs.

(b)Includes foreign investments of $881 million.

(c)Includes foreign investments of $156 million.

(d)Includes foreign investments of $93 million.

(e)Includes foreign investments of $5 million.

(f)Includes foreign investments of $35 million.

(g)Includes foreign investments of $153 million.

Expected Cash Flows – The following table provides information about benefit payments expected to be paid by the pension plan for each of the following calendar years (in millions):

2022	$	204
2023	$	208
2024	$	209
2025	$	210
2026	$	214
2027 – 2031	$	1,033

Net Periodic Income – The components of net periodic income for the plans are as follows:

	Pension Benefits						Postretirement Benefits
	2021		2020		2019		2021		2020		2019
			(millions)
Service cost	$	90	$	85	$	80	$	2	$	1	$	1
Interest cost	64		92		114		4		8		9
Expected return on plan assets	(339)		(321)		(312)		—		—		—
Amortization of actuarial loss	24		18		—		5		3		—
Amortization of prior service benefit	(1)		(1)		(1)		(15)		(16)		(15)
Special termination benefits	—		16		19		—		—		—
Net periodic income at NEE	$	(162)	$	(111)	$	(100)	$	(4)	$	(4)	$	(5)
Net periodic income allocated to FPL	$	(108)	$	(84)	$	(61)	$	(4)	$	(4)	$	(4)

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Other Comprehensive Income – The components of net periodic income recognized in OCI for the pension plan are as follows:

	2021		2020		2019
	(millions)
Net gains (losses) (net of $29 tax expense, $13 tax expense and $10 tax benefit, respectively)	$	95	$	42	$	(36)
Amortization of unrecognized losses (net of $2 tax expense and $1 tax expense, respectively)	6		5		—
Total	$	101	$	47	$	(36)

Regulatory Assets (Liabilities) – The components of net periodic income recognized during the year in regulatory assets (liabilities) for the pension plan are as follows:

	2021		2020
	(millions)
Prior service cost (benefit)	$	(1)	$	1
Unrecognized gains	(226)		(89)
Amortization of prior service benefit	—		1
Amortization of unrecognized losses	(16)		(12)
Total	$	(243)	$	(99)

The assumptions used to determine net periodic pension income for the pension plan are as follows:

	2021		2020		2019
Discount rate	2.53	%	3.22	%	4.26	%
Salary increase	4.40	%	4.40	%	4.40	%
Expected long-term rate of return, net of investment management fees(a)	7.35	%	7.35	%	7.35	%
Weighted-average interest crediting rate	3.82	%	3.83	%	3.88	%

______________________

(a)In developing the expected long-term rate of return on assets assumption for its pension plan, NEE evaluated input, including other qualitative and quantitative factors, from its actuaries and consultants, as well as information available in the marketplace. 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. NEE also considered its pension fund's historical compounded returns.

Employee Contribution Plan – NEE offers an employee retirement savings plan which allows eligible participants to contribute a percentage of qualified compensation through payroll deductions. NEE makes matching contributions to participants' accounts. Defined contribution expense pursuant to this plan was approximately $66 million, $64 million and $58 million for NEE ($42 million, $40 million and $40 million for FPL) for the years ended December 31, 2021, 2020 and 2019, respectively.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

13. Debt

Long-term debt consists of the following:

	December 31,
	2021					2020
	Maturity Date	Balance		Weighted- Average Interest Rate		Balance			Weighted- Average Interest Rate
		(millions)				(millions)
FPL:
First mortgage bonds – fixed	2023 – 2051	$	14,290	4.20	%	$	13,090		4.32	%
Pollution control, solid waste disposal and industrial development revenue bonds – primarily variable(a)	2022 – 2050	1,407		0.15	%	1,407			0.17	%
Senior unsecured notes – primarily variable(b)(c)	2022 – 2071	2,697		1.37	%	2,621			1.55	%
Other long-term debt – variable(c)	2022 – 2046	307		0.82	%	300			0.70	%
Unamortized debt issuance costs and discount		(191)				(182)
Total long-term debt of FPL		18,510				17,236
Less current portion of long-term debt		536				354
Long-term debt of FPL, excluding current portion		17,974				16,882
NEER:
NextEra Energy Resources:
Senior secured limited-recourse long-term debt – variable(c)(d)	2024 – 2037	3,100		1.74	%	2,621			1.99	%
Senior secured limited-recourse long-term loans – fixed	2028 – 2049	2,475		3.30	%	704			3.59	%
Other long-term debt – primarily variable(c)(d)	2024 – 2048	785		2.50	%	450			2.72	%
NEET – long-term debt – primarily fixed(d)	2022 – 2049	1,151		2.69	%	937			3.09	%
Unamortized debt issuance costs and premium		(92)				(65)
Total long-term debt of NEER		7,419				4,647
Less current portion of long-term debt		664				239
Long-term debt of NEER, excluding current portion		6,755				4,408
NEECH:
Debentures – fixed	2023 – 2052	10,990		2.21	%	11,540		(d)	2.86	%
Debentures – variable(c)	2022 – 2023	3,850		0.56	%	1,225			0.80	%
Debentures, related to NEE's equity units – fixed	2024 – 2025	6,000		1.46	%	6,000			1.46	%
Junior subordinated debentures – primarily fixed(d)	2057 – 2082	3,723		4.54	%	3,693			4.78	%
Japanese yen denominated long-term debt – primarily variable(c)(d)(e)	2023 – 2030	582		1.49	%	650			1.49	%
Australian dollar denominated long-term debt – fixed(e)	2026	360		2.20	%	385			2.20	%
Other long-term debt – fixed	2022	186		0.92	%	221			0.92	%
Other long-term debt – variable(c)	2023 – 2024	1,245		0.64	%	600			0.70	%
Unamortized debt issuance costs, premium		(120)				(115)
Total long-term debt of NEECH		26,816				24,199
Less current portion of long-term debt		585				3,545
Long-term debt of NEECH, excluding current portion		26,231				20,654
Total long-term debt		$	50,960			$	41,944

______________________

(a)Includes variable rate tax exempt bonds that permit individual bondholders to tender the bonds for purchase at any time prior to maturity. In the event these variable rate tax exempt bonds are tendered for purchase, they would be remarketed by a designated remarketing agent in accordance with the related indenture. If the remarketing is unsuccessful, FPL would be required to purchase these variable rate tax exempt bonds. At December 31, 2021, these variable rate tax exempt bonds totaled approximately $1,375 million. All variable rate tax exempt bonds tendered for purchase have been successfully remarketed. FPL's syndicated revolving credit facilities are available to support the purchase of the variable rate tax exempt bonds. Variable interest rate is established at various intervals by the remarketing agent.

(b)At December 31, 2021, includes approximately $882 million of floating rate notes that permit individual noteholders to require repayment at specified dates prior to maturity. FPL’s syndicated revolving credit facilities are available to support the purchase of the floating rate notes.

(c)Variable rate is based on an underlying index plus a specified margin.

(d)Interest rate contracts, primarily swaps, have been entered into with respect to certain of these debt issuances. See Note 3.

(e)Foreign currency contracts have been entered into with respect to these debt issuances. See Note 3.

As of December 31, 2021, minimum annual maturities of long-term debt for NEE are approximately $1,785 million, $8,394 million, $3,672 million, $6,536 million and $1,322 million for 2022, 2023, 2024, 2025 and 2026, respectively. The respective amounts for FPL are approximately $536 million, $1,548 million, $646 million, $1,700 million and $0.2 million.

At December 31, 2021 and 2020, short-term borrowings had a weighted-average interest rate of 0.39% (0.27% for FPL) and 0.35% (0.28% for FPL), respectively. Subsidiaries of NEE, including FPL, had credit facilities with available capacity at December 31, 2021 of approximately $12.1 billion ($4.6 billion for FPL), of which approximately $11.1 billion ($4.6 billion for FPL)

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

relate to revolving line of credit facilities and $1.0 billion (none for FPL) relate to letter of credit facilities. Certain of the revolving line of credit facilities provide for the issuance of letters of credit which at December 31, 2021 had available capacity of approximately $1.9 billion ($647 million for FPL). The issuance of letters of credit under certain revolving line of credit facilities is subject to the aggregate commitment of the relevant banks to issue letters of credit under the applicable facility.

NEE has guaranteed certain payment obligations of NEECH, including most of those under NEECH's debt, including all of its debentures and commercial paper issuances, as well as most of its payment guarantees and indemnifications. NEECH has guaranteed certain debt and other obligations of subsidiaries within the NEER segment.

In August 2019, NEECH completed a remarketing of $1.5 billion aggregate principal amount of its Series I Debentures due September 1, 2021 (Series I Debentures) that were issued in August 2016 as components of equity units issued concurrently by NEE (August 2016 equity units). The Series I Debentures are fully and unconditionally guaranteed by NEE. In connection with the remarketing of the Series I Debentures, the interest rate on the Series I Debentures was reset to 2.403% per year, and interest is payable on March 1 and September 1 of each year, commencing September 1, 2019. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the August 2016 equity units, in the third quarter of 2019, NEE issued approximately 9.5 million shares of common stock (38.2 million shares after giving effect to the four-for-one stock split of NEE common stock effective October 26, 2020 (2020 stock split) in exchange for $1.5 billion.

As a result of the 2020 stock split (and adjustments related to the dividend rate), the fixed settlement rates of NEE’s three outstanding series of Corporate Units have been adjusted as described below. In addition, the Corporate Units provide that the applicable market value (as described below) for each series of Corporate Units will also be adjusted (when determined) to give effect to the 2020 stock split and certain other anti-dilution adjustments to determine the applicable settlement rate. However, for purposes of the presentation below, corresponding adjustments were instead made to the reference prices and the threshold appreciation prices for each series of Corporate Units to present the practical effect of the antidilution adjustments as of December 31, 2021.

In September 2019, NEE sold $1.5 billion of equity units (initially consisting of Corporate Units). Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series J Debenture due September 1, 2024, issued in the principal amount of $1,000 by NEECH. Each stock purchase contract requires the holder to purchase by no later than September 1, 2022 (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range described in the following sentence. If purchased on the final settlement date, as of December 31, 2021, the number of shares issued per equity unit would (subject to antidilution adjustments) range from 0.8973 shares if the applicable market value of a share of NEE common stock is less than or equal to $55.72 (the adjusted reference price) to 0.7181 shares if the applicable market value of a share is equal to or greater than $69.66 (the adjusted threshold appreciation price), with the applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending August 29, 2022. Total annual distributions on the equity units are at the rate of 4.872%, consisting of interest on the debentures (2.10% per year) and payments under the stock purchase contracts (2.772% per year). The interest rate on the debentures is expected to be reset on or after March 1, 2022. A holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit. The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder's obligation to purchase NEE common stock under the related stock purchase contract. If a successful remarketing does not occur on or before the third business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE.

In February 2020, NEE sold $2.5 billion of equity units (initially consisting of Corporate Units). Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series K Debenture due March 1, 2025, issued in the principal amount of $1,000 by NEECH. Each stock purchase contract requires the holder to purchase by no later than March 1, 2023 (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range described in the following sentence. If purchased on the final settlement date, as of December 31, 2021, the number of shares issued per equity unit would (subject to antidilution adjustments) range from 0.7104 shares if the applicable market value of a share of NEE common stock is less than or equal to $70.39 (the adjusted reference price) to 0.5681 shares if the applicable market value of a share is equal to or greater than $87.99 (the adjusted threshold appreciation price), with the applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending February 24, 2023. Total annual distributions on the equity units are at the rate of 5.279%, consisting of interest on the debentures (1.84% per year) and payments under the stock purchase contracts (3.439% per year). The interest rate on the debentures is expected to be reset on or after September 1, 2022. A holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit. The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder's obligation to purchase NEE common stock under the related stock purchase contract. If a successful remarketing does not occur on or before the third

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE.

In September 2020, NEE sold $2.0 billion of equity units (initially consisting of Corporate Units). Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series L Debenture due September 1, 2025, issued in the principal amount of $1,000 by NEECH. Each stock purchase contract requires the holder to purchase by no later than September 1, 2023 (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range described in the following sentence. If purchased on the final settlement date, as of December 31, 2021, the number of shares issued per equity unit would (subject to antidilution adjustments) range from 0.6776 shares if the applicable market value of a share of NEE common stock is less than or equal to $73.79 (the adjusted reference price) to 0.5421 shares if the applicable market value of a share is equal to or greater than $92.24 (the adjusted threshold appreciation price), with the applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending August 29, 2023. Total annual distributions on the equity units are at the rate of 6.219%, consisting of interest on the debentures (0.509% per year) and payments under the stock purchase contracts (5.710% per year). The interest rate on the debentures is expected to be reset on or after March 1, 2023. A holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit. The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder's obligation to purchase NEE common stock under the related stock purchase contract. If a successful remarketing does not occur on or before the third business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE.

Prior to the issuance of NEE’s common stock, the stock purchase contracts, if dilutive, will be reflected in NEE’s diluted earnings per share calculations using the treasury stock method. Under this method, the number of shares of NEE common stock used in calculating diluted earnings per share is deemed to be increased by the excess, if any, of the number of shares that would be issued upon settlement of the stock purchase contracts over the number of shares that could be purchased by NEE in the market, at the average market price during the period, using the proceeds receivable upon settlement.

In January 2022, FPL sold $1.5 billion principal amount of its First Mortgage Bonds, 2.45% Series due February 3, 2032 and sold $1.0 billion principal amount of its Floating Rate Notes, Series due January 12, 2024.

14. Equity

Earnings Per Share – The reconciliation of NEE's basic and diluted earnings per share attributable to NEE is as follows:

	Years Ended December 31,
	2021		2020		2019
	(millions, except per share amounts)
Numerator – net income attributable to NEE	$	3,573	$	2,919	$	3,769
Denominator:
Weighted-average number of common shares outstanding – basic	1,962.5		1,959.0		1,927.9
Equity units, stock options, performance share awards and restricted stock(a)	9.7		9.8		14.0
Weighted-average number of common shares outstanding – assuming dilution	1,972.2		1,968.8		1,941.9
Earnings per share attributable to NEE:
Basic	$	1.82	$	1.49	$	1.95
Assuming dilution	$	1.81	$	1.48	$	1.94

______________________

(a)Calculated using the treasury stock method. Performance share awards are included in diluted weighted-average number of common shares outstanding based upon what would be issued if the end of the reporting period was the end of the term of the award.

Common shares issuable pursuant to equity units, stock options and/or performance share awards, as well as restricted stock which were not included in the denominator above due to their antidilutive effect were approximately 30.5 million, 27.1 million and 3.0 million for the years ended December 31, 2021, 2020 and 2019, respectively.

On September 14, 2020, NEE's board of directors approved a four-for-one split of NEE common stock effective October 26, 2020. NEE's authorized common stock increased from 800 million to 3.2 billion shares. All share and share-based data included in NEE's consolidated financial statements reflect the effect of the 2020 stock split.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Potentially Dilutive Securities at NEP – NEP senior unsecured convertible notes, when outstanding, are potentially dilutive securities to NEE. In June 2021 and December 2020, NEP issued $500 million and $600 million, respectively, principal amount of new senior unsecured convertible notes. Holders of these notes may convert all or a portion of the notes in accordance with the related indenture. Upon conversion, NEP will pay cash up to the principal amount of the notes to be converted and pay or deliver, as the case may be, cash, NEP common units or a combination of cash and common units, at NEP's election, in respect of the remainder, if any, of NEP's conversion obligation in excess of the principal amount of the notes being converted.

Common Stock Dividend Restrictions – NEE's charter does not limit the dividends that may be paid on its common stock. FPL's mortgage securing FPL's first mortgage bonds contains provisions which, under certain conditions, restrict the payment of dividends and other distributions to NEE. These restrictions do not currently limit FPL's ability to pay dividends to NEE.

Stock-Based Compensation – Net income for the years ended December 31, 2021, 2020 and 2019 includes approximately $119 million, $107 million and $100 million, respectively, of compensation costs and $19 million, $21 million and $17 million, respectively, of income tax benefits related to stock-based compensation arrangements. Compensation cost capitalized for the years ended December 31, 2021, 2020 and 2019 was not material. At December 31, 2021, there were approximately $148 million of unrecognized compensation costs related to nonvested/nonexercisable stock-based compensation arrangements. These costs are expected to be recognized over a weighted-average period of 2.8 years.

At December 31, 2021, approximately 84 million shares of common stock were authorized for awards to officers, employees and non-employee directors of NEE and its subsidiaries under NEE's: (a) 2021 Long Term Incentive Plan, (b) 2017 Non-Employee Directors Stock Plan and (c) earlier equity compensation plans under which shares are reserved for issuance under existing grants, but no additional shares are available for grant under the earlier plans. NEE satisfies restricted stock and performance share awards by issuing new shares of its common stock or by purchasing shares of its common stock in the open market. NEE satisfies stock option exercises by issuing new shares of its common stock. NEE generally grants most of its stock-based compensation awards in the first quarter of each year.

Restricted Stock and Performance Share Awards – Restricted stock typically vests within three years after the date of grant and is subject to, among other things, restrictions on transferability prior to vesting. The fair value of restricted stock is measured based upon the closing market price of NEE common stock as of the date of grant. Performance share awards are typically payable at the end of a three-year performance period if the specified performance criteria are met. The fair value for the majority of performance share awards is estimated based upon the closing market price of NEE common stock as of the date of grant less the present value of expected dividends, multiplied by an estimated performance multiple which is subsequently trued up based on actual performance. 

The activity in restricted stock and performance share awards for the year ended December 31, 2021 was as follows:

	Shares/Units	Weighted- Average Grant Date Fair Value Per Share/Units
Restricted Stock:
Nonvested balance, January 1, 2021	1,674,242	$	50.26
Granted	1,013,039	$	82.69
Vested	(835,919)	$	48.06
Forfeited	(33,630)	$	69.63
Nonvested balance, December 31, 2021	1,817,732	$	68.09
Performance Share Awards:
Nonvested balance, January 1, 2021	1,938,608	$	47.46
Granted	1,297,680	$	54.82
Vested	(1,738,904)	$	37.53
Forfeited	(85,235)	$	64.84
Nonvested balance, December 31, 2021	1,412,149	$	61.22

The weighted-average grant date fair value per share of restricted stock granted for the years ended December 31, 2020 and 2019 was $68.25 and $46.64 respectively. The weighted-average grant date fair value per share of performance share awards granted for the years ended December 31, 2020 and 2019 was $46.09 and $34.75, respectively.

The total fair value of restricted stock and performance share awards vested was $186 million, $177 million and $125 million for the years ended December 31, 2021, 2020 and 2019, respectively.

105

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Options – Options typically vest within three years after the date of grant and have a maximum term of ten years. The exercise price of each option granted equals the closing market price of NEE common stock on the date of grant. The fair value of the options is estimated on the date of the grant using the Black-Scholes option-pricing model and based on the following assumptions:

	2021	2020	2019
Expected volatility(a)	17.32 – 17.75%	14.63 – 16.31%	14.20 – 14.31%
Expected dividends	2.30 – 2.44%	2.50 – 2.72%	2.85 – 2.93%
Expected term (years)(b)	7.0	7.0	7.0
Risk-free rate	0.80 – 1.27%	0.49 – 1.52%	2.24 – 2.54%

______________________

(a)Based on historical experience.

(b)Based on historical exercise and post-vesting cancellation experience adjusted for outstanding awards.

Option activity for the year ended December 31, 2021 was as follows:

	Shares Underlying Options	Weighted- Average Exercise Price Per Share		Weighted- Average Remaining Contractual Term (years)	Aggregate Intrinsic Value (millions)
Balance, January 1, 2021	9,618,204	$	38.32
Granted	1,220,265	$	83.33
Exercised	(738,516)	$	20.08
Forfeited	(86,641)	$	71.19
Balance, December 31, 2021	10,013,312	$	44.87	6.0	$	486
Exercisable, December 31, 2021	7,235,572	$	35.35	5.0	$	420

The weighted-average grant date fair value of options granted was $9.82, $7.08 and $5.01 per share for the years ended December 31, 2021, 2020 and 2019, respectively. The total intrinsic value of stock options exercised was approximately $49 million, $71 million and $81 million for the years ended December 31, 2021, 2020 and 2019, respectively.

Cash received from option exercises was approximately $15 million, $30 million and $34 million for the years ended December 31, 2021, 2020 and 2019, respectively. The tax benefits realized from options exercised were approximately $11 million, $17 million and $19 million for the years ended December 31, 2021, 2020 and 2019, respectively.

Preferred Stock – NEE's charter authorizes the issuance of 100 million shares of serial preferred stock, $0.01 par value, none of which are outstanding. FPL's charter authorizes the issuance of 10,414,100 shares of preferred stock, $100 par value, 5 million shares of subordinated preferred stock, no par value, and 5 million shares of preferred stock, no par value, none of which are outstanding.

106

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Accumulated Other Comprehensive Income (Loss) – The components of AOCI, net of tax, are as follows:

	Accumulated Other Comprehensive Income (Loss)
	Net Unrealized Gains (Losses) on Cash Flow Hedges			Net Unrealized Gains (Losses) on Available for Sale Securities			Defined Benefit Pension and Other Benefits Plans			Net Unrealized Gains (Losses) on Foreign Currency Translation			Other Comprehensive Income (Loss) Related to Equity Method Investees		Total
	(millions)
Balances, December 31, 2018	$	(55)		$	(7)		$	(65)		$	(63)		$	2	$	(188)
Other comprehensive income (loss) before reclassifications	—			20			(46)			22			1		(3)
Amounts reclassified from AOCI	29		(a)	(2)		(b)	(3)		(c)	—			—		24
Net other comprehensive income (loss)	29			18			(49)			22			1		21
Less other comprehensive income attributable to noncontrolling interests	—			—			—			1			—		1
Acquisition of Gulf Power (see Note 6)	(1)			—			—			—			—		(1)
Balances, December 31, 2019	(27)			11			(114)			(42)			3		(169)
Other comprehensive income before reclassifications	—			12			37			13			1		63
Amounts reclassified from AOCI	12		(a)	(3)		(b)	2		(c)	—			—		11
Net other comprehensive income	12			9			39			13			1		74
Less other comprehensive income attributable to noncontrolling interests	—			—			—			7			—		7
Impact of disposal of a business	23		(d)	—			—			(13)		(d)	—		10
Balances, December 31, 2020	8			20			(75)			(49)			4		(92)
Other comprehensive income (loss) before reclassifications	—			(11)			95			(1)			1		84
Amounts reclassified from AOCI	6		(a)	(4)		(b)	5		(c)	—			—		7
Net other comprehensive income (loss)	6			(15)			100			(1)			1		91
Less other comprehensive loss attributable to noncontrolling interests	—			—			—			(1)			—		(1)
Balances, December 31, 2021	$	14		$	5		$	25		$	(49)		$	5	$	—
Attributable to noncontrolling interests	$	—		$	—		$	—		$	6		$	—	$	6

______________________

(a)Reclassified to interest expense in NEE's consolidated statements of income. See Note 3 – Income Statement Impact of Derivative Instruments.

(b)Reclassified to gains on disposal of investments and other property – net in NEE's consolidated statements of income.

(c)Reclassified to other net periodic benefit income in NEE's consolidated statements of income.

(d)Reclassified to gains on disposal of businesses/assets – net and interest expense in NEE's consolidated statements of income. See Note 3 – Income Statement Impact of Derivative Instruments and Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

107

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

15. Commitments and Contingencies

Commitments – NEE and its subsidiaries have made commitments in connection with a portion of their projected capital expenditures. Capital expenditures at FPL include, among other things, the cost for construction of additional facilities and equipment to meet customer demand, as well as capital improvements to and maintenance of existing facilities. At NEER, capital expenditures include, among other things, the cost, including capitalized interest, for construction and development of wind and solar projects, the procurement of nuclear fuel and the cost to maintain existing rate-regulated transmission facilities, as well as equity contributions to a joint venture for the development and construction of a rate-regulated transmission facility. Also see Note 4 – Contingent Consideration.

At December 31, 2021, estimated capital expenditures for 2022 through 2026 were as follows:

	2022		2023		2024		2025		2026		Total
	(millions)
FPL:
Generation:(a)
New(b)	$	1,825	$	1,670	$	1,635	$	1,210	$	995	$	7,335
Existing	1,605		1,465		1,220		685		750		5,725
Transmission and distribution(c)	4,035		3,760		3,870		4,760		5,075		21,500
Nuclear fuel	155		110		145		145		120		675
General and other	875		625		715		740		665		3,620
Total	$	8,495	$	7,630	$	7,585	$	7,540	$	7,605	$	38,855
NEER:(d)
Wind(e)	$	2,630	$	240	$	50	$	35	$	30	$	2,985
Solar(f)	3,445		1,010		170		25		10		4,660
Battery storage	270		120		—		—		5		395
Nuclear, including nuclear fuel	200		150		200		210		210		970
Rate-regulated transmission	220		85		55		30		30		420
Other	440		85		95		60		70		750
Total	$	7,205	$	1,690	$	570	$	360	$	355	$	10,180

______________________

(a)Includes AFUDC of approximately $75 million, $85 million, $60 million, $50 million and $40 million for 2022 through 2026, respectively.

(b)Includes land, generation structures, transmission interconnection and integration and licensing.

(c)Includes AFUDC of approximately $50 million, $45 million, $40 million, $15 million and $0 million for 2022 through 2026, respectively.

(d)Represents capital expenditures for which applicable internal approvals and also, if required, regulatory approvals have been received.

(e)Consists of capital expenditures for new wind projects, repowering of existing wind projects and related transmission totaling approximately 2,852 MW.

(f)Includes capital expenditures for new solar projects (including solar plus battery storage projects) and related transmission totaling approximately 5,946 MW.

The above estimates are subject to continuing review and adjustment and actual capital expenditures may vary significantly from these estimates.

In addition to guarantees noted in Note 8 with regards to NEP, NEECH has guaranteed or provided indemnifications or letters of credit related to third parties, including certain obligations of investments in joint ventures accounted for under the equity method, totaling approximately $484 million at December 31, 2021. These obligations primarily related to guaranteeing the residual value of certain financing leases. Payment guarantees and related contracts with respect to unconsolidated entities for which NEE or one of its subsidiaries are the guarantor are recorded at fair value and are included in noncurrent other liabilities on NEE’s consolidated balance sheets. Management believes that the exposure associated with these guarantees is not material.

Contracts – In addition to the commitments made in connection with the estimated capital expenditures included in the table in Commitments above, FPL has firm commitments under long-term contracts primarily for the transportation of natural gas with expiration dates through 2042.

At December 31, 2021, NEER has entered into contracts with expiration dates through 2033 primarily for the purchase of wind turbines, wind towers and solar modules and related construction and development activities, as well as for the supply of uranium, and the conversion, enrichment and fabrication of nuclear fuel, and has made commitments for the construction of a rate-regulated transmission facility. Approximately $4.3 billion of related commitments are included in the estimated capital expenditures table in Commitments above. In addition, NEER has contracts primarily for the transportation and storage of natural gas with expiration dates through 2040.

108

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The required capacity and/or minimum payments under contracts, including those discussed above at December 31, 2021, were estimated as follows:

	2022		2023		2024		2025		2026		Thereafter
	(millions)
FPL(a)	$	1,025	$	980	$	955	$	900	$	825	$	8,570
NEER(b)(c)(d)	$	4,400	$	365	$	185	$	85	$	65	$	570

_______________________

(a)Includes approximately $415 million, $410 million, $410 million, $405 million, $400 million and $5,960 million in 2022 through 2026 and thereafter, respectively, of firm commitments related to the natural gas transportation agreements with Sabal Trail and Florida Southeast Connection, LLC. The charges associated with these agreements are recoverable through the fuel clause and totaled approximately $419 million, $386 million and $316 million for the years ended December 31, 2021, 2020 and 2019, respectively, of which $105 million, $108 million and $108 million, respectively, were eliminated in consolidation at NEE.      

(b)Excludes commitments related to equity contributions and a 20-year natural gas transportation agreement (approximately $70 million per year) with a joint venture, in which NEER has a 31.9% equity investment, that is constructing a natural gas pipeline. These commitments are subject to the completion of construction of the pipeline which has a very low probability of completion. See Note 4 – Nonrecurring Fair Value Measurements.

(c)Includes approximately $370 million of commitments to invest in technology and other investments through 2031. See Note 9 – Other.

(d)Includes approximately $610 million, $20 million, $5 million, $5 million, $0 million and $5 million for 2022 through 2026 and thereafter, respectively, of joint obligations of NEECH and NEER.

Insurance – Liability for accidents at nuclear power plants is governed by the Price-Anderson Act, which limits the liability of nuclear reactor owners to the amount of insurance available from both private sources and an industry retrospective payment plan. In accordance with this Act, NEE maintains $450 million of private liability insurance per site, which is the maximum obtainable, except at Duane Arnold which obtained an exemption from the NRC and maintains a $100 million private liability insurance limit. Each site, except Duane Arnold, participates in a secondary financial protection system, which provides up to $13.1 billion of liability insurance coverage per incident at any nuclear reactor in the U.S. Under the secondary financial protection system, NEE is subject to retrospective assessments of up to $963 million ($550 million for FPL), plus any applicable taxes, per incident at any nuclear reactor in the U.S., payable at a rate not to exceed $143 million ($82 million for FPL) per incident per year. NextEra Energy Resources and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook and St. Lucie Unit No. 2, which approximates $16 million and $20 million, plus any applicable taxes, per incident, respectively.

NEE participates in a nuclear insurance mutual company that provides $2.75 billion of limited insurance coverage per occurrence per site for property damage, decontamination and premature decommissioning risks at its nuclear plants and a sublimit of $1.5 billion for non-nuclear perils, except for Duane Arnold which has a limit of $50 million for property damage, decontamination risks and non-nuclear perils. NEE participates in co-insurance of 10% of the first $400 million of losses per site per occurrence, except at Duane Arnold. The proceeds from such insurance, however, must first be used for reactor stabilization and site decontamination before they can be used for plant repair. NEE also participates in an insurance program that provides limited coverage for replacement power costs if a nuclear plant is out of service for an extended period of time because of an accident. In the event of an accident at one of NEE's or another participating insured's nuclear plants, NEE could be assessed up to $163 million ($104 million for FPL), plus any applicable taxes, in retrospective premiums in a policy year. NextEra Energy Resources and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook, Duane Arnold and St. Lucie Unit No. 2, which approximates $2 million, $2 million and $4 million, plus any applicable taxes, respectively.

Due to the high cost and limited coverage available from third-party insurers, NEE does not have property insurance coverage for a substantial portion of either its transmission and distribution property or natural gas pipeline assets. If FPL's future storm restoration costs exceed the storm and property insurance reserve, such storm restoration costs may be recovered, subject to prudence review by the FPSC, through surcharges approved by the FPSC or through securitization provisions pursuant to Florida law. See Note 1 – Storm Funds, Storm Reserves and Storm Cost Recovery.

In the event of a loss, the amount of insurance available might not be adequate to cover property damage and other expenses incurred. Uninsured losses and other expenses, to the extent not recovered from customers in the case of FPL, would be borne by NEE and FPL and could have a material adverse effect on NEE's and FPL's financial condition, results of operations and liquidity.

16. Segment Information

The tables below present information for NEE's and FPL's reportable segments. NEE's segments include its reportable segments, the FPL segment, a rate-regulated utility business, and NEER, which is comprised of competitive energy and rate-regulated transmission businesses, as well as an operating segment of NEE, Gulf Power, a rate-regulated utility business. FPL's reportable segments include the FPL segment and Gulf Power. See Note 6 – Merger of FPL and Gulf Power Company. Corporate and Other for each of NEE and FPL represents other business activities, such as purchase accounting adjustments for Gulf Power Company, includes eliminating entries, and may include the net effect of rounding. See Note 2 for information regarding NEE's and FPL's operating revenues.

109

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

NEE's segment information is as follows:

	2021
	FPL Segment		Gulf Power		NEER(a)		Corp. and Other		NEE Consolidated
	(millions)
Operating revenues	$	12,600	$	1,503	$	3,053	$	(87)	$	17,069
Operating expenses – net	$	8,418	$	1,170	$	4,434	$	211	$	14,233
Gains (losses) on disposal of businesses/assets – net	$	1	$	—	$	78	$	(2)	$	77
Interest expense	$	588	$	28	$	367	$	287	$	1,270
Depreciation and amortization	$	1,968	$	297	$	1,576	$	83	$	3,924
Equity in earnings of equity method investees	$	—	$	—	$	666	$	—	$	666
Income tax expense (benefit)(b)	$	767	$	71	$	(395)	$	(95)	$	348
Net income (loss)	$	2,935	$	271	$	(147)	$	(232)	$	2,827
Net income (loss) attributable to NEE	$	2,935	$	271	$	599	$	(232)	$	3,573
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	6,785	$	782	$	8,363	$	147	$	16,077
Property, plant and equipment – net	$	52,728	$	5,499	$	40,900	$	221	$	99,348
Total assets	$	68,197	$	7,209	$	62,113	$	3,393	$	140,912
Investment in equity method investees	$	—	$	—	$	6,150	$	9	$	6,159

	2020
	FPL Segment		Gulf Power		NEER(a)		Corp. and Other		NEE Consolidated
	(millions)
Operating revenues	$	11,662	$	1,398	$	5,046	$	(109)	$	17,997
Operating expenses – net	$	7,862	$	1,081	$	4,125	$	166	$	13,234
Gains (losses) on disposal of businesses/assets – net	$	—	$	—	$	363	$	(10)	$	353
Interest expense	$	600	$	41	$	659	$	650	$	1,950
Depreciation and amortization	$	2,246	$	281	$	1,460	$	65	$	4,052
Equity in losses of equity method investees	$	—	$	—	$	(1,351)	$	—	$	(1,351)
Income tax expense (benefit)(b)	$	610	$	67	$	(416)	$	(217)	$	44
Net income (loss)	$	2,650	$	238	$	(19)	$	(500)	$	2,369
Net income (loss) attributable to NEE	$	2,650	$	238	$	531	$	(500)	$	2,919
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	6,680	$	1,012	$	6,893	$	25	$	14,610
Property, plant and equipment – net	$	48,933	$	4,946	$	37,842	$	82	$	91,803
Total assets	$	61,610	$	6,725	$	55,633	$	3,716	$	127,684
Investment in equity method investees	$	—	$	—	$	5,713	$	15	$	5,728

_________________________

(a)Interest expense allocated from NEECH is based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy Resources' subsidiaries. Residual NEECH corporate interest expense is included in Corporate and Other.

(b)NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 – Income Taxes.

110

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

	2019
	FPL Segment		Gulf Power		NEER(a)		Corp. and Other		NEE Consolidated
	(millions)
Operating revenues	$	12,192	$	1,487	$	5,639	$	(114)	$	19,204
Operating expenses – net	$	8,895	$	1,216	$	4,037	$	109	$	14,257
Gains (losses) on disposal of businesses/assets – net	$	5	$	—	$	402	$	(1)	$	406
Interest expense	$	594	$	55	$	873	$	727	$	2,249
Depreciation and amortization	$	2,524	$	247	$	1,387	$	58	$	4,216
Equity in earnings (losses) of equity method investees	$	—	$	—	$	67	$	(1)	$	66
Income tax expense (benefit)(b)	$	441	$	42	$	162	$	(197)	$	448
Net income (loss)	$	2,334	$	180	$	1,426	$	(552)	$	3,388
Net income (loss) attributable to NEE	$	2,334	$	180	$	1,807	$	(552)	$	3,769
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	5,755	$	729	$	6,505	$	4,473	$	17,462
Property, plant and equipment – net	$	45,074	$	4,763	$	32,042	$	131	$	82,010
Total assets	$	57,188	$	5,855	$	51,516	$	3,132	$	117,691
Investment in equity method investees	$	—	$	—	$	7,453	$	—	$	7,453

_________________________

(a)Interest expense allocated from NEECH is based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy Resources' subsidiaries. Residual NEECH corporate interest expense is included in Corporate and Other.

(b)NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 – Income Taxes.

FPL's segment information is as follows:

	2021								2020								2019
	FPL Segment		Gulf Power		Corp. and Other		FPL Consoli- dated		FPL Segment		Gulf Power		Corp. and Other		FPL Consoli-dated		FPL Segment		Gulf Power		Corp. and Other		FPL Consoli-dated
	(millions)
Operating revenues	$	12,600	$	1,503	$	(1)	$	14,102	$	11,662	$	1,398	$	—	$	13,060	$	12,192	$	1,487	$	1	$	13,680
Operating expenses – net (a)	$	8,418	$	1,170	$	(2)	$	9,586	$	7,862	$	1,081	$	(3)	$	8,940	$	8,895	$	1,216	$	(10)	$	10,101
Interest expense	$	588	$	28	$	(1)	$	615	$	600	$	41	$	—	$	641	$	594	$	55	$	—	$	649
Depreciation and amortization	$	1,968	$	297	$	1	$	2,266	$	2,246	$	281	$	(1)	$	2,526	$	2,524	$	247	$	—	$	2,771
Income tax expense	$	767	$	71	$	—	$	838	$	610	$	67	$	1	$	678	$	441	$	42	$	1	$	484
Net income	$	2,935	$	271	$	—	$	3,206	$	2,650	$	238	$	2	$	2,890	$	2,334	$	180	$	5	$	2,519
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	6,785	$	782	$	3	$	7,570	$	6,680	$	1,012	$	(13)	$	7,679	$	5,755	$	729	$	1	$	6,485
Property, plant and equipment – net	$	52,728	$	5,499	$	—	$	58,227	$	48,933	$	4,946	$	—	$	53,879	$	45,074	$	4,763	$	—	$	49,837
Total assets	$	68,197	$	7,209	$	2,661	$	78,067	$	61,610	$	6,725	$	2,666	$	71,001	$	57,188	$	5,855	$	2,647	$	65,690

_________________________

(a)FPL's income statement line for total operating expenses – net includes gains (losses) on disposal of businesses/assets – net.

111

Item 9.  Changes in and Disagreements With Accountants on Accounting and Financial Disclosure

None

Item 9A.  Controls and Procedures

Disclosure Controls and Procedures

As of December 31, 2021, each of NEE and FPL had performed an evaluation, under the supervision and with the participation of its management, including NEE's and FPL's chief executive officer and chief financial officer, of the effectiveness of the design and operation of each company's disclosure controls and procedures (as defined in the Securities Exchange Act of 1934 Rules 13a-15(e) and 15d-15(e)). Based upon that evaluation, the chief executive officer and the chief financial officer of each of NEE and FPL concluded that the company's disclosure controls and procedures were effective as of December 31, 2021.

Internal Control Over Financial Reporting

(a)Management's Annual Report on Internal Control Over Financial Reporting

See Item 8. Financial Statements and Supplementary Data.

(b)Attestation Report of the Independent Registered Public Accounting Firm

See Item 8. Financial Statements and Supplementary Data.

(c)Changes in Internal Control Over Financial Reporting

NEE and FPL are continuously seeking to improve the efficiency and effectiveness of their operations and of their internal controls. This results in refinements to processes throughout NEE and FPL. However, there has been no change in NEE's or FPL's internal control over financial reporting (as defined in the Securities Exchange Act of 1934 Rules 13a-15(f) and 15d-15(f)) that occurred during NEE's and FPL's most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, NEE's or FPL's internal control over financial reporting.

Item 9B.  Other Information

None

Item 9C.  Disclosure Regarding Foreign Jurisdictions that Prevent Inspections

Not applicable

112

PART III

Item 10.  Directors, Executive Officers and Corporate Governance

The information required by this item will be included under the headings "Business of the Annual Meeting," "Information About NextEra Energy and Management" and "Corporate Governance and Board Matters" in NEE's Proxy Statement which will be filed with the SEC in connection with the 2022 Annual Meeting of Shareholders (NEE's Proxy Statement) and is incorporated herein by reference, or is included in Item 1. Business – Information About Our Executive Officers.

NEE has adopted the NextEra Energy, Inc. Code of Ethics for Senior Executive and Financial Officers (the Senior Financial Executive Code), which is applicable to the chief executive officer, the chief financial officer, the chief accounting officer and other senior executive and financial officers. The Senior Financial Executive Code is available under Corporate Governance in the Investor Relations section of NEE’s internet website at www.nexteraenergy.com. Any amendments or waivers of the Senior Financial Executive Code which are required to be disclosed to shareholders under SEC rules will be disclosed on the NEE website at the address listed above.

Item 11.  Executive Compensation

The information required by this item will be included in NEE's Proxy Statement under the headings "Executive Compensation" and "Corporate Governance and Board Matters" and is incorporated herein by reference.

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

The information required by this item relating to security ownership of certain beneficial owners and management will be included in NEE's Proxy Statement under the heading "Information About NextEra Energy and Management" and is incorporated herein by reference.

Securities Authorized For Issuance Under Equity Compensation Plans(a)

NEE's equity compensation plan information at December 31, 2021 is as follows:

Plan Category	Number of securities to be issued upon exercise of outstanding options, warrants and rights (a)		Weighted-average exercise price of outstanding options, warrants and rights (b)			Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a)) (c)
Equity compensation plans approved by security holders	15,231,663	(a)	$	44.87	(b)	66,846,051	(c)
Equity compensation plans not approved by security holders	—		—			—
Total	15,231,663		$	44.87		66,846,051

______________________

(a)Includes an aggregate of 10,013,312 outstanding options, 3,451,310 unvested performance share awards (at maximum payout), 1,016,262 deferred fully vested performance shares, 344,760 deferred stock awards and 359,843 unvested restricted stock units (including future reinvested dividends) under the NextEra Energy, Inc. 2021 Long Term Incentive Plan and former LTIPs, and 46,176 fully vested shares deferred by directors under the NextEra Energy, Inc. 2017 Non-Employee Directors Stock Plan, and its predecessors the FPL Group, Inc. 2007 Non-Employee Directors Stock Plan and the FPL Group, Inc. Amended and Restated Non-Employee Directors Stock Plan.

(b)Relates to outstanding options only.

(c)Includes 65,008,350 shares under the NextEra Energy, Inc. 2021 Long Term Incentive Plan and 1,837,701 shares under the NextEra Energy, Inc. 2017 Non-Employee Directors Stock Plan.

Item 13.  Certain Relationships and Related Transactions, and Director Independence

The information required by this item, to the extent applicable, will be included in NEE's Proxy Statement under the heading "Corporate Governance and Board Matters" and is incorporated herein by reference.

113

Item 14.  Principal Accountant Fees and Services

NEE – The information required by this item will be included in NEE's Proxy Statement under the heading "Audit-Related Matters" and is incorporated herein by reference.

FPL – The following table presents fees billed for professional services rendered by Deloitte & Touche LLP, the member firms of Deloitte Touche Tohmatsu, and their respective affiliates (collectively, Deloitte & Touche) for the fiscal years ended December 31, 2021 and 2020. The amounts presented below reflect allocations from NEE for FPL's portion of the fees, as well as amounts billed directly to FPL.

	2021		2020(a)
Audit fees(b)	$	3,834,000	$	3,613,000
Audit-related fees(c)	752,000		1,150,000
Tax fees(d)	404,000		486,000
All other fees(e)	57,000		6,000
Total	$	5,047,000	$	5,255,000

______________________

(a)Amounts have been retrospectively adjusted to include fees paid by Gulf Power Company.

(b)Audit fees consist of fees billed for professional services rendered for the audit of FPL's and NEE's annual consolidated financial statements for the fiscal year, the reviews of the financial statements included in FPL's and NEE's Quarterly Reports on Form 10-Q during the fiscal year and the audit of the effectiveness of internal control over financial reporting, comfort letters, and consents.

(c)Audit-related fees consist of fees billed for assurance and related services that are reasonably related to the performance of the audit or review of FPL's and NEE's consolidated financial statements and are not reported under audit fees. These fees primarily relate to audits of subsidiary financial statements and attestation services.

(d)Tax fees consist of fees billed for professional services rendered for tax compliance, tax advice and tax planning. These fees primarily relate to research and development tax credit advice and planning services.

(e)All other fees consist of fees for products and services other than the services reported under the other named categories. In 2021 and 2020, these fees relate to training, and in 2021 also relate to advisory services for development of a request for proposal on financial systems implementation services.

In accordance with the requirements of the Sarbanes-Oxley Act of 2002, the Audit Committee Charter and the Audit Committee's pre-approval policy for services provided by the independent registered public accounting firm, all services performed by Deloitte & Touche are approved in advance by the Audit Committee, except for audits of certain trust funds where the fees are paid by the trust. Permitted services specifically identified in an appendix to the pre-approval policy are pre-approved by the Audit Committee each year. This pre-approval allows management to request the specified permitted services on an as-needed basis during the year, provided any such services are reviewed with the Audit Committee at its next regularly scheduled meeting. Any permitted service for which the fee is expected to exceed $500,000, or that involves a service not listed on the pre-approval list, must be specifically approved by the Audit Committee prior to commencement of such service. The Audit Committee has delegated to the Chair of the committee the right to approve audit, audit-related, tax and other services, within certain limitations, between meetings of the Audit Committee, provided any such decision is presented to the Audit Committee at its next regularly scheduled meeting. At each Audit Committee meeting (other than meetings held to review earnings materials), the Audit Committee reviews a schedule of services for which Deloitte & Touche has been engaged since the prior Audit Committee meeting under existing pre-approvals and the estimated fees for those services. In 2021 and 2020, none of the amounts presented above represent services provided to NEE or FPL by Deloitte & Touche that were approved by the Audit Committee after services were rendered pursuant to Rule 2-01(c)(7)(i)(C) of Regulation S-X (which provides for a waiver of the otherwise applicable pre-approval requirement if certain conditions are met).

114

PART IV

Item 15.  Exhibits and Financial Statement Schedules

			Page(s)
(a)	1.	Financial Statements
		Management's Report on Internal Control Over Financial Reporting	56
		Attestation Report of Independent Registered Public Accounting Firm	57
		Report of Independent Registered Public Accounting Firm (PCAOB ID 34)	58
		NEE:
		Consolidated Statements of Income	60
		Consolidated Statements of Comprehensive Income	61
		Consolidated Balance Sheets	62
		Consolidated Statements of Cash Flows	63
		Consolidated Statements of Equity	64
		FPL:
		Consolidated Statements of Income	65
		Consolidated Balance Sheets	66
		Consolidated Statements of Cash Flows	67
		Consolidated Statements of Common Shareholder's Equity	68
		Notes to Consolidated Financial Statements	69 – 111
	2.	Financial Statement Schedules – Schedules are omitted as not applicable or not required.
	3.	Exhibits (including those incorporated by reference)
		Certain exhibits listed below refer to "FPL Group" and "FPL Group Capital," and were effective prior to the change of the name FPL Group, Inc. to NextEra Energy, Inc., and of the name FPL Group Capital Inc to NextEra Energy Capital Holdings, Inc., during 2010.

Exhibit Number	Description	NEE	FPL
*2(a)	Agreement and Plan of Merger, dated as of December 18, 2020, between Gulf Power Company and Florida Power & Light Company (filed as Exhibit 2 to Form 8-K dated December 18, 2020, File No. 2-27612)		x
*3(i)a	Restated Articles of Incorporation of NextEra Energy, Inc. (filed as Exhibit 3(i) to Form 8-K dated October 26, 2020, File No. 1-8841)	x
*3(i)b	Restated Articles of Incorporation of Florida Power & Light Company (filed as Exhibit 3(i)b to Form 10-K for the year ended December 31, 2010, File No. 2-27612)		x
*3(i)c	Articles of Merger of Florida Power & Light Company and Gulf Power Company (filed as Exhibit 3(i)(c) to Form 10-K for the year ended December 31, 2020, File No. 2-27612)		x
*3(ii)a	Amended and Restated Bylaws of NextEra Energy, Inc., effective October 14, 2016 (filed as Exhibit 3(ii)(b) to Form 8-K dated October 14, 2016, File No. 1-8841)	x
*3(ii)b	Amended and Restated Bylaws of Florida Power & Light Company, as amended through October 17, 2008 (filed as Exhibit 3(ii)b to Form 10-Q for the quarter ended September 30, 2008, File No. 2-27612)		x

115

Exhibit Number	Description	NEE	FPL
*4(a)	Mortgage and Deed of Trust dated as of January 1, 1944, as amended, between Florida Power & Light Company and Deutsche Bank Trust Company Americas, Trustee (filed as Exhibit B-3, File No. 2-4845; Exhibit 7(a), File No. 2-7126; Exhibit 7(a), File No. 2-7523; Exhibit 7(a), File No. 2-7990; Exhibit 7(a), File No. 2-9217; Exhibit 4(a)-5, File No. 2-10093; Exhibit 4(c), File No. 2-11491; Exhibit 4(b)-1, File No. 2-12900; Exhibit 4(b)-1, File No. 2-13255; Exhibit 4(b)-1, File No. 2-13705; Exhibit 4(b)-1, File No. 2-13925; Exhibit 4(b)-1, File No. 2-15088; Exhibit 4(b)-1, File No. 2-15677; Exhibit 4(b)-1, File No. 2-20501; Exhibit 4(b)-1, File No. 2-22104; Exhibit 2(c), File No. 2-23142; Exhibit 2(c), File No. 2-24195; Exhibit 4(b)-1, File No. 2-25677; Exhibit 2(c), File No. 2-27612; Exhibit 2(c), File No. 2-29001; Exhibit 2(c), File No. 2-30542; Exhibit 2(c), File No. 2-33038; Exhibit 2(c), File No. 2-37679; Exhibit 2(c), File No. 2-39006; Exhibit 2(c), File No. 2-41312; Exhibit 2(c), File No. 2-44234; Exhibit 2(c), File No. 2-46502; Exhibit 2(c), File No. 2-48679; Exhibit 2(c), File No. 2-49726; Exhibit 2(c), File No. 2-50712; Exhibit 2(c), File No. 2-52826; Exhibit 2(c), File No. 2-53272; Exhibit 2(c), File No. 2-54242; Exhibit 2(c), File No. 2-56228; Exhibits 2(c) and 2(d), File No. 2-60413; Exhibits 2(c) and 2(d), File No. 2-65701; Exhibit 2(c), File No. 2-66524; Exhibit 2(c), File No. 2-67239; Exhibit 4(c), File No. 2-69716; Exhibit 4(c), File No. 2-70767; Exhibit 4(b), File No. 2-71542; Exhibit 4(b), File No. 2-73799; Exhibits 4(c), 4(d) and 4(e), File No. 2-75762; Exhibit 4(c), File No. 2-77629; Exhibit 4(c), File No. 2-79557; Exhibit 99(a) to Post-Effective Amendment No. 5 to Form S-8, File No. 33-18669; Exhibit 99(a) to Post-Effective Amendment No. 1 to Form S-3, File No. 33-46076; Exhibit 4(b) to Form 10-Q for the quarter ended June 30, 1995, File No. 1-3545; Exhibit 4(a) to Form 10-Q for the quarter ended March 31, 1996, File No. 1-3545; Exhibit 4(o), File No. 333-102169; Exhibit 4(k) to Post-Effective Amendment No. 1 to Form S-3, File No. 333-102172; Exhibit 4(l) to Post-Effective Amendment No. 2 to Form S-3, File No. 333-102172; Exhibit 4(m) to Post-Effective Amendment No. 3 to Form S-3, File No. 333-102172; Exhibit 4(f) to Amendment No. 1 to Form S-3, File No. 333-125275; Exhibit 4(y) to Post-Effective Amendment No. 2 to Form S-3, File Nos. 333-116300, 333-116300-01 and 333-116300-02; Exhibit 4(z) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-116300, 333-116300-01 and 333-116300-02; Exhibit 4(b) to Form 10-Q for the quarter ended March 31, 2006, File No. 2-27612; Exhibit 4(a) to Form 8-K dated April 17, 2007, File No. 2-27612; Exhibit 4 to Form 8-K dated January 16, 2008, File No. 2-27612; Exhibit 4(a) to Form 8-K dated March 17, 2009, File No. 2-27612; Exhibit 4 to Form 8-K dated February 9, 2010, File No. 2-27612; Exhibit 4 to Form 8-K dated December 9, 2010, File No. 2-27612; Exhibit 4(a) to Form 8-K dated June 10, 2011, File No. 2-27612; Exhibit 4 to Form 8-K dated December 13, 2011, File No. 2-27612; Exhibit 4 to Form 8-K dated May 15, 2012, File No. 2-27612; Exhibit 4 to Form 8-K dated December 20, 2012, File No. 2-27612; Exhibit 4 to Form 8-K dated June 5, 2013, File No. 2-27612; Exhibit 4 to Form 8-K dated May 15, 2014, File No. 2-27612; Exhibit 4 to Form 8-K dated September 10, 2014, File No. 2-27612; Exhibit 4 to Form 8-K dated November 19, 2015, File No. 2-27612; Exhibit 4(b) to Form 10-K for the year ended December 31, 2017, File No. 2-27612; Exhibit 4(a) to Form 10-Q for the quarter ended March 31, 2018, File No. 2-27612; Exhibit 4(j), File Nos. 333-226056, 333-226056-01 and 333-226056-02; Exhibit 4(k), File Nos. 333-226056, 333-226056-01 and 333-226056-02; Exhibit 4(a) to Form 10-Q for the quarter ended March 31, 2019, File No. 2-27612; Exhibit 4(f) to Form 10-Q for the quarter ended September 30, 2019, File No. 2-27612; Exhibit 4(e) to Form 10-Q for the quarter ended March 31, 2020, File No. 2-27612; and Exhibit 4(b) to Form 10-K for the year ended December 31, 2020, File No. 2-27612)	x	x
4(b)	One Hundred Thirty-Third Supplemental Indenture dated as of November 1, 2021 between Florida Power & Light Company and Deutsche Bank Trust Company Americas, Trustee	x	x
4(c)	One Hundred Thirty-Fourth Supplemental Indenture dated as of January 1, 2022 between Florida Power & Light Company and Deutsche Bank Trust Company Americas, Trustee	x	x
*4(d)	Indenture (For Unsecured Debt Securities), dated as of November 1, 2017, between Florida Power & Light Company and The Bank of New York Mellon (as Trustee) (filed as Exhibit 4(a) to Form 8-K dated November 6, 2017, File No. 2-27612)	x	x
*4(e)	Officer's Certificate of Florida Power & Light Company, dated June 15, 2018, creating the Floating Rate Notes, Series due June 15, 2068 (filed as Exhibit 4 to Form 8-K dated June 15, 2018, File No. 2-27612)	x	x

116

Exhibit Number	Description	NEE	FPL
*4(f)	Officer's Certificate of Florida Power & Light Company, dated November 14, 2018, creating the Floating Rate Notes, Series due November 14, 2068 (filed as Exhibit 4 to Form 8-K dated November 14, 2018, File No. 2-27612)	x	x
*4(g)	Officer's Certificate of Florida Power & Light Company, dated March 27, 2019, creating the Floating Rate Notes, Series due March 27, 2069 (filed as Exhibit 4(b) to Form 8-K dated March 27, 2019, File No. 2-27612)	x	x
*4(h)	Officer's Certificate of Florida Power & Light Company, dated March 13, 2020, creating the Floating Rate Notes, Series due March 13, 2070 (filed as Exhibit 4 to Form 8-K dated March 13, 2020, File No. 2-27612)	x	x
*4(i)	Officer's Certificate of Florida Power & Light Company, dated August 24, 2020, creating the Floating Rate Notes, Series due August 24, 2070 (filed as Exhibit 4 to Form 8-K dated August 24, 2020, File No. 2-27612)	x	x
*4(j)	Officer's Certificate of Florida Power & Light Company, dated March 1, 2021, creating the Floating Rate Notes, Series due March 1, 2071 (filed as Exhibit 4 to Form 8-K dated March 1, 2021, File No. 2-27612)	x	x
*4(k)	Officer's Certificate of Florida Power & Light Company, dated May 10, 2021, creating the Floating Rate Notes, Series due May 10, 2023 (filed as Exhibit 4 to Form 8-K dated May 10, 2021, File No. 2-27612)	x	x
4(l)	Officer's Certificate of Florida Power & Light Company, dated January 14, 2022, creating the Floating Rate Notes, Series due January 12, 2024	x	x
*4(m)	Indenture (For Unsecured Debt Securities), dated as of June 1, 1999, between FPL Group Capital Inc and The Bank of New York Mellon (as Trustee) (filed as Exhibit 4(a) to Form 8-K dated July 16, 1999, File No. 1-8841)	x
*4(n)	First Supplemental Indenture to Indenture (For Unsecured Debt Securities) dated as of June 1, 1999, dated as of September 21, 2012, between NextEra Energy Capital Holdings, Inc. and The Bank of New York Mellon, as Trustee (filed as Exhibit 4(e) to Form 10-Q for the quarter ended September 30, 2012, File No. 1-8841)	x
*4(o)	Guarantee Agreement, dated as of June 1, 1999, between FPL Group, Inc. (as Guarantor) and The Bank of New York Mellon (as Guarantee Trustee) (filed as Exhibit 4(b) to Form 8-K dated July 16, 1999, File No. 1-8841)	x
*4(p)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated April 28, 2017, creating the 3.55% Debentures, Series due May 1, 2027 (filed as Exhibit 4 to Form 8-K dated April 28, 2017, File No. 1-8841)	x
*4(q)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated February 27, 2019, creating the Floating Rate Debentures, Series due February 25, 2022 (filed as Exhibit 4(a) to Form 8-K dated February 27, 2019, File No. 1-8841)	x
*4(r)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated April 4, 2019, creating the 3.50% Debentures, Series due April 1, 2029 (filed as Exhibit 4(d) to Form 8-K dated April 4, 2019, File No. 1-8841)	x
*4(s)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated September 9, 2019, creating the Series J Debentures due September 1, 2024 (filed as Exhibit 4(e) to Form 10-Q for the quarter ended September 30, 2019, File No. 1-8841)	x
*4(t)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated October 3, 2019, creating the 2.75% Debentures, Series due November 1, 2029 (filed as Exhibit 4 to Form 8-K dated October 3, 2019, File No. 1-8841)	x
*4(u)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated February 21, 2020, creating the Series K Debentures due March 1, 2025 (filed as Exhibit 4(c) to Form 10-Q for the quarter ended March 31, 2020, File No. 1-8841)	x
*4(v)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated May 12, 2020, creating the 2.25% Debentures, Series due June 1, 2030 (filed as Exhibit 4 to Form 8-K dated May 12, 2020, File No. 1-8841)	x
*4(w)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated September 18, 2020, creating the Series L Debentures due September 1, 2025 (filed as Exhibit 4(e) to Form 10-Q for the quarter ended September 30, 2020, File No. 1-8841)	x
*4(x)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated February 22, 2021, creating the Floating Rate Debentures, Series due February 22, 2023 (filed as Exhibit 4 to Form 8-K dated February 22, 2021, File No. 1-8841)	x

117

Exhibit Number	Description	NEE	FPL
*4(y)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated March 17, 2021, creating the 0.65% Debentures, Series due March 1, 2023 (filed as Exhibit 4(ak), File Nos. 333-254632, 333-254632-01 and 333-254632-02)	x
*4(z)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated March 17, 2021, creating the Floating Rate Debentures, Series due March 1, 2023 (filed as Exhibit 4(al), File Nos. 333-254632, 333-254632-01 and 333-254632-02)	x
*4(aa)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated June 8, 2021, creating the 1.90% Debentures, Series due June 15, 2028 (filed as Exhibit 4 to Form 8-K dated June 8, 2021, File No. 1-8841)	x
*4(bb)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated November 3, 2021, creating the Floating Rate Debentures, Series due November 3, 2023 (filed as Exhibit 4 to Form 8-K dated November 3, 2021, File No. 1-8841)	x
*4(cc)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated December 13, 2021, creating the 1.875% Debentures, Series due January 15, 2027 (filed as Exhibit 4(a) to Form 8-K dated December 13, 2021, File No. 1-8841)	x
*4(dd)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated December 13, 2021, creating the 2.440% Debentures, Series due January 15, 2032 (filed as Exhibit 4(b) to Form 8-K dated December 13, 2021, File No. 1-8841)	x
*4(ee)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated December 13, 2021, creating the 3.000% Debentures, Series due January 15, 2052 (filed as Exhibit 4(c) to Form 8-K dated December 13, 2021, File No. 1-8841)	x
*4(ff)	Indenture (For Unsecured Subordinated Debt Securities relating to Trust Securities), dated as of March 1, 2004, among FPL Group Capital Inc, FPL Group, Inc. (as Guarantor) and The Bank of New York Mellon (as Trustee) (filed as Exhibit 4(au) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-102173, 333-102173-01, 333-102173-02 and 333-102173-03)	x
*4(gg)	Indenture (For Unsecured Subordinated Debt Securities), dated as of September 1, 2006, among FPL Group Capital Inc, FPL Group, Inc. (as Guarantor) and The Bank of New York Mellon (as Trustee) (filed as Exhibit 4(a) to Form 8-K dated September 19, 2006, File No. 1-8841)	x
*4(hh)	First Supplemental Indenture to Indenture (For Unsecured Subordinated Debt Securities) dated as of September 1, 2006, dated as of November 19, 2012, between NextEra Energy Capital Holdings, Inc., NextEra Energy, Inc. as Guarantor, and The Bank of New York Mellon, as Trustee (filed as Exhibit 2 to Form 8-A dated January 16, 2013, File No. 1-33028)	x
*4(ii)	Officer's Certificate of FPL Group Capital Inc and FPL Group, Inc., dated September 19, 2006, creating the Series B Enhanced Junior Subordinated Debentures due 2066 (filed as Exhibit 4(c) to Form 8-K dated September 19, 2006, File No. 1-8841)	x
*4(jj)	Replacement Capital Covenant, dated September 19, 2006, by FPL Group Capital Inc and FPL Group, Inc. relating to FPL Group Capital Inc's Series B Enhanced Junior Subordinated Debentures due 2066 (filed as Exhibit 4(d) to Form 8-K dated September 19, 2006, File No. 1-8841)	x
*4(kk)	Amendment, dated November 9, 2016, to the Replacement Capital Covenant, dated September 19, 2006, by NextEra Energy Capital Holdings, Inc. (formerly known as FPL Group Capital Holdings Inc) and NextEra Energy, Inc. (formerly known as FPL Group, Inc.), relating to FPL Group Capital Inc's Series B Enhanced Junior Subordinated Debentures due 2066 (filed as Exhibit 4(cc) to Form 10-K for the year ended December 31, 2016, File No. 1-8841)	x
*4(ll)	Officer's Certificate of FPL Group Capital Inc and FPL Group, Inc., dated June 12, 2007, creating the Series C Junior Subordinated Debentures due 2067 (filed as Exhibit 4(a) to Form 8-K dated June 12, 2007, File No. 1-8841)	x
*4(mm)	Replacement Capital Covenant, dated June 12, 2007, by FPL Group Capital Inc and FPL Group, Inc. relating to FPL Group Capital Inc's Series C Junior Subordinated Debentures due 2067 (filed as Exhibit 4(b) to Form 8-K dated June 12, 2007, File No. 1-8841)	x
*4(nn)	Amendment, dated November 9, 2016, to the Replacement Capital Covenant, dated June 12, 2007 by NextEra Energy Capital Holdings, Inc. (formerly known as FPL Group Capital Holdings Inc) and NextEra Energy, Inc. (formerly known as FPL Group, Inc.), relating to FPL Group Capital Inc's Series C Junior Subordinated Debentures due 2067 (filed as Exhibit 4(hh) to Form 10-K for the year ended December 31, 2016, File No. 1-8841)	x

118

Exhibit Number	Description	NEE	FPL
*4(oo)	Officer's Certificate of NextEra Energy Capital Holdings, Inc. and NextEra Energy, Inc., dated September 29, 2017, creating the Series L Junior Subordinated Debentures due September 29, 2057 (filed as Exhibit 4(c) to Form 8-K dated September 29, 2017, File No. 1-8841)	x
*4(pp)	Officer's Certificate of NextEra Energy Capital Holdings, Inc. and NextEra Energy, Inc., dated November 2, 2017, creating the Series M Junior Subordinated Debentures due December 1, 2077 (filed as Exhibit 4(a) to Form 8-K dated November 2, 2017, File No. 1-8841)	x
*4(qq)	Officer's Certificate of NextEra Energy Capital Holdings, Inc. and NextEra Energy, Inc., dated March 15, 2019, creating the Series N Junior Subordinated Debentures due March 1, 2079 (filed as Exhibit 4 to Form 8-K dated March 15, 2019, File No. 1-8841)	x
*4(rr)	Officer's Certificate of NextEra Energy Capital Holdings, Inc. and NextEra Energy, Inc., dated April 4, 2019, creating the Series O Junior Subordinated Debentures due May 1, 2079 (filed as Exhibit 4(e) to Form 8-K dated April 4, 2019, File No. 1-8841)	x
*4(ss)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated December 14, 2021, creating the Series P Junior Subordinated Debentures due March 15, 2082 (filed as Exhibit 4 to Form 8-K dated December 14, 2021, File No. 1-8841)	x
*4(tt)	Purchase Contract Agreement, dated as of September 1, 2019, between NextEra Energy, Inc. and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(c) to Form 10-Q for the quarter ended September 30, 2019, File No. 1-8841)	x
*4(uu)	Pledge Agreement, dated as of September 1, 2019, between NextEra Energy, Inc., Deutsche Bank Trust Company Americas, as Collateral Agent, Custodial Agent and Securities Intermediary, and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(d) to Form 10-Q for the quarter ended September 30, 2019, File No. 1-8841)	x
*4(vv)	Purchase Contract Agreement, dated as of February 1, 2020, between NextEra Energy, Inc. and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(a) to Form 10-Q for the quarter ended March 31, 2020, File No. 1-8841)	x
*4(ww)	Pledge Agreement, dated as of February 1, 2020, between NextEra Energy, Inc., Deutsche Bank Trust Company Americas, as Collateral Agent, Custodial Agent and Securities Intermediary, and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(b) to Form 10-Q for the quarter ended March 31, 2020, File No. 1-8841)	x
*4(xx)	Purchase Contract Agreement, dated as of September 1, 2020, between NextEra Energy, Inc. and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(c) to Form 10-Q for the quarter ended September 30, 2020, File No. 1-8841)	x
*4(yy)	Pledge Agreement, dated as of September 1, 2020, between NextEra Energy, Inc., Deutsche Bank Trust Company Americas, as Collateral Agent, Custodial Agent and Securities Intermediary, and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(d) to Form 10-Q for the quarter ended September 30, 2020, File No. 1-8841)	x
*4(zz)	Senior Note Indenture dated as of January 1, 1998, between Florida Power & Light Company (as successor to Gulf Power Company) and Computershare Trust Company, N.A., as Successor Trustee, and certain indentures supplemental thereto (filed as Exhibit 4.1 to Form 8-K dated June 17, 1998, File No. 0-2429; Exhibit 4.2 to Form 8-K dated September 9, 2010, File No. 1-31737; Exhibit 4.2 to Form 8-K dated May 15, 2012, File No. 1-31737; Exhibit 4.2 to Form 8-K dated June 10, 2013, File No. 1-31737; Exhibit 4.2 to Form 8-K dated September 16, 2014, File No. 1-31737; Exhibit 4.2 to Form 8-K dated May 15, 2017, File No. 1-31737; and Exhibit 4(ddd) to Form 10-K for the year ended December 31, 2020, File No. 2-27612)	x	x
4(aaa)	Description of Securities Registered Pursuant to Section 12 of the Securities Exchange Act of 1934	x
*10(a)	FPL Group, Inc. Supplemental Executive Retirement Plan, amended and restated effective April 1, 1997 (SERP) (filed as Exhibit 10(a) to Form 10-K for the year ended December 31, 1999, File No. 1-8841)	x	x
*10(b)	FPL Group, Inc. Supplemental Executive Retirement Plan, amended and restated effective January 1, 2005 (Restated SERP) (filed as Exhibit 10(b) to Form 8-K dated December 12, 2008, File No. 1-8841)	x	x

119

Exhibit Number	Description	NEE	FPL
*10(c)	Amendment Number 1 to the Restated SERP changing name to NextEra Energy, Inc. Supplemental Executive Retirement Plan (filed as Exhibit 10(b) to Form 10-Q for the quarter ended June 30, 2010, File No. 1-8841)	x	x
*10(d)	Appendix A1 (revised as of March 16, 2016) to the NextEra Energy, Inc. Supplemental Executive Retirement Plan (filed as Exhibit 10(d) to Form 10-K dated December 31, 2017, File No. 1-8841)	x	x
*10(e)	Appendix A2 (revised as of October 1, 2017) to the NextEra Energy, Inc. Supplemental Executive Retirement Plan (filed as Exhibit 10(e) to Form 10-K dated December 31, 2017, File No. 1-8841)	x	x
*10(f)	Supplement to the Restated SERP relating to a special credit to certain executive officers and other officers effective February 15, 2008 (filed as Exhibit 10(g) to Form 10-K for the year ended December 31, 2007, File No. 1-8841)	x	x
*10(g)	NextEra Energy, Inc. (formerly known as FPL Group, Inc.) Amended and Restated Long-Term Incentive Plan, most recently amended and restated on May 22, 2009 (filed as Exhibit 10(a) to Form 10-Q for the quarter ended June 30, 2009, File No. 1-8841)	x	x
*10(h)	NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan (filed as Exhibit 10(c) to Form 8-K dated March 16, 2012, File No. 1-8841)	x	x
*10(i)	Form of Performance Share Award Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(b) to Form 10-Q for the quarter ended March 31, 2018, File No. 1-8841)	x	x
*10(j)	Form of Restricted Stock Award Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(c) to Form 10-Q for the quarter ended March 31, 2018, File No. 1-8841)	x	x
*10(k)	Form of Restricted Stock Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(a) to Form 10-Q for the quarter ended March 31, 2021, File No. 1-8841)	x	x
*10(l)	Form of Restricted Stock Unit Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(b) to Form 10-Q for the quarter ended March 31, 2021, File No. 1-8841)	x	x
*10(m)	Form of Restricted Stock Unit Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(c) to Form 10-Q for the quarter ended March 31, 2021, File No. 1-8841)	x	x
*10(n)	Form of Restricted Stock Unit Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(d) to Form 10-Q for the quarter ended March 31, 2021, File No. 1-8841)	x	x
*10(o)	Form of Non-Qualified Stock Option Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(f) to Form 10-Q for the quarter ended March 31, 2016, File No. 1-8841)	x	x
*10(p)	Form of Non-Qualified Stock Option Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(g) to Form 10-Q for the quarter ended March 31, 2016, File No. 1-8841)	x	x
*10(q)	Form of Non-Qualified Stock Option agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(d) to Form 10-Q for the quarter ended March 31, 2018, File No. 1-8841)	x	x
*10(r)	Form of Non-Qualified Stock Option Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(e) to Form 10-Q for the quarter ended March 31, 2021, File No. 1-8841)	x	x
*10(s)	Form of Non-Qualified Stock Option Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(f) to Form 10-Q for the quarter ended March 31, 2021, File No. 1-8841)	x	x
*10(t)	Form of Performance Share Award Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(g) to Form 10-Q for the quarter ended March 31, 2021, File No. 1-8841)	x	x
*10(u)	Form of Performance Share Award Agreement under the NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(h) to Form 10-Q for the quarter ended March 31, 2021, File No. 1-8841)	x	x
*10(v)	NextEra Energy, Inc. 2021 Long Term Incentive Plan (filed as Exhibit 10 to Form 8-K dated May 20, 2021, File No. 1-8841)	x	x

120

Exhibit Number	Description	NEE	FPL
*10(w)	Form of Non-Qualified Stock Option Agreement under the NextEra Energy, Inc. 2021 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(b) to Form 10‑Q for the quarter ended June 30, 2021, File No. 1-8841)	x	x
*10(x)	Form of Performance Share Award Agreement under the NextEra Energy, Inc. 2021 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(c) to Form 10-Q for the quarter ended June 30, 2021, File No. 1-8841)	x	x
*10(y)	Form of Restricted Stock Award Agreement under the NextEra Energy, Inc. 2021 Long Term Incentive Plan for certain executive officers (filed as Exhibit 10(d) to Form 10-Q for the quarter ended June 30, 2021, File No. 1-8841)	x	x
*10(z)	Form of FPL Group, Inc. Amended and Restated Long-Term Incentive Plan Amended and Restated Deferred Stock Award Agreement effective February 12, 2010 between FPL Group, Inc. and James L. Robo (filed as Exhibit 10(dd) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)	x	x
*10(aa)	Form of Deferred Stock Award Agreement under NextEra Energy, Inc. Amended and Restated 2011 Long Term Incentive Plan (filed as Exhibit 10(a) to Form 8-K dated March 16, 2012, File No. 1-8841)	x	x
*10(bb)	NextEra Energy, Inc. 2013 Executive Annual Incentive Plan (filed as Exhibit 10(c) to Form 8-K dated October 11, 2012, File No. 1-8841)	x	x
*10(cc)	NextEra Energy, Inc. Deferred Compensation Plan effective January 1, 2005 as amended and restated through February 11, 2016 (filed as Exhibit 10(h) to Form 10-Q for the quarter ended March 31, 2016, File No. 1-8841)	x	x
*10(dd)	FPL Group, Inc. Deferred Compensation Plan, amended and restated effective January 1, 2003 (filed as Exhibit 10(k) to Form 10-K for the year ended December 31, 2002, File No. 1-8841)	x	x
*10(ee)	FPL Group, Inc. Executive Long-Term Disability Plan effective January 1, 1995 (filed as Exhibit 10(g) to Form 10-K for the year ended December 31, 1995, File No. 1-8841)	x	x
*10(ff)	FPL Group, Inc. Amended and Restated Non-Employee Directors Stock Plan, as amended and restated October 13, 2006 (filed as Exhibit 10(b) to Form 10-Q for the quarter ended September 30, 2006, File No. 1-8841)	x
*10(gg)	FPL Group, Inc. 2007 Non-Employee Directors Stock Plan (filed as Exhibit 99 to Form S-8, File No. 333-143739)	x
*10(hh)	NextEra Energy, Inc. 2017 Non-Employee Directors Stock Plan, as amended and restated as of May 18, 2017 (filed as Exhibit 10 to Form 10-Q for the quarter ended June 30, 2017, File No. 1-8841)	x
*10(ii)	NextEra Energy, Inc. Non-Employee Director Compensation Summary effective January 1, 2021 (filed as Exhibit 10(bb) to Form 10-K for the year ended December 31, 2020, File No. 1-8841)	x
10(jj)	NextEra Energy, Inc. Non-Employee Director Compensation Summary effective January 1, 2022	x
*10(kk)	Form of Amended and Restated Executive Retention Employment Agreement effective December 10, 2009 between FPL Group, Inc. and each of James L. Robo and Charles E. Sieving (filed as Exhibit 10(nn) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)	x	x
*10(ll)	Executive Retention Employment Agreement between NextEra Energy, Inc. and Eric E. Silagy dated as of May 2, 2012 (filed as Exhibit 10(b) to Form 10-Q for the quarter ended June 30, 2012, File No. 1-8841)	x	x
*10(mm)	Form of 2012 409A Amendment to NextEra Energy, Inc. Executive Retention Employment Agreement effective October 11, 2012 between NextEra Energy, Inc. and each of James L. Robo, Eric E. Silagy and Charles E. Sieving (filed as Exhibit 10(ddd) to Form 10-K for the year ended December 31, 2012, File No. 1-8841)	x	x
*10(nn)	Executive Retention Employment Agreement between NextEra Energy, Inc. and Deborah H. Caplan dated as of April 23, 2013 (filed as Exhibit 10(e) to Form 10-Q for the quarter ended June 30, 2013, File No. 1-8841)	x	x
*10(oo)	Executive Retention Employment Agreement between NextEra Energy, Inc. and Miguel Arechabala dated as of January 1, 2014 (filed as Exhibit 10(bbb) to Form 10‑K for the year ended December 31, 2013, File No. 1-8841)	x	x

121

Exhibit Number	Description	NEE	FPL
*10(pp)	Executive Retention Employment Agreement between NextEra Energy, Inc. and John W. Ketchum dated as of March 4, 2016 (filed as Exhibit 10(i) to Form 10-Q for the quarter ended March 31, 2016, File No. 1-8841)	x	x
*10(qq)	Executive Retention Employment Agreement between NextEra Energy, Inc. and Rebecca J. Kujawa dated as of March 1, 2019 (filed as Exhibit 10(b) to Form 10-Q for the quarter ended March 31, 2019, File No. 1-8841)	x	x
*10(rr)	Executive Retention Employment Agreement between NextEra Energy, Inc. and Ronald Reagan dated as of January 1, 2020 (filed as Exhibit 10(tt) to Form 10-K for the year ended December 31, 2019, File No. 1-8841)	x	x
*10(ss)	Executive Retention Employment Agreement between NextEra Energy, Inc. and Robert P. Coffey dated as of June 14, 2021 (filed as Exhibit 10(e) to Form 10-Q for the quarter ended June 30, 2021, File No. 1-8841)	x	x
*10(tt)	NextEra Energy, Inc. Executive Severance Benefit Plan effective February 26, 2013 (filed as Exhibit 10(eee) to Form 10-K for the year ended December 31, 2012, File No. 1-8841)	x	x
*10(uu)	Guarantee Agreement between FPL Group, Inc. and FPL Group Capital Inc, dated as of October 14, 1998 (filed as Exhibit 10(y) to Form 10-K for the year ended December 31, 2001, File No. 1-8841)	x
*10(vv)	NextEra Energy Partners, LP 2014 Long-Term Incentive Plan (filed as Exhibit 10.8 to Form 8-K dated July 1, 2014, File No. 1-36518)	x
*10(ww)	Form of Restricted Unit Award Agreement under the NextEra Energy Partners, LP 2014 Long-Term Incentive Plan (filed as Exhibit 10.17 to Form 10-K for the year ended December 31, 2017, File No. 1-36518)	x
21	Subsidiaries of NextEra Energy, Inc.	x
22	Guaranteed Securities	x
23	Consent of Independent Registered Public Accounting Firm	x	x
31(a)	Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of NextEra Energy, Inc.	x
31(b)	Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer of NextEra Energy, Inc.	x
31(c)	Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of Florida Power & Light Company		x
31(d)	Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer of Florida Power & Light Company		x
32(a)	Section 1350 Certification of NextEra Energy, Inc.	x
32(b)	Section 1350 Certification of Florida Power & Light Company		x
101.INS	XBRL Instance Document – the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document	x	x
101.SCH	Inline XBRL Schema Document	x	x
101.PRE	Inline XBRL Presentation Linkbase Document	x	x
101.CAL	Inline XBRL Calculation Linkbase Document	x	x
101.LAB	Inline XBRL Label Linkbase Document	x	x
101.DEF	Inline XBRL Definition Linkbase Document	x	x
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)	x	x

______________________

* Incorporated herein by reference

NEE and FPL agree to furnish to the SEC upon request any instrument with respect to long-term debt that NEE and FPL have not filed as an exhibit pursuant to the exemption provided by Item 601(b)(4)(iii)(A) of Regulation S-K.

Item 16.  Form 10-K Summary

Not applicable

122

NEXTERA ENERGY, INC. SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized and in the capacities and on the date indicated.

NextEra Energy, Inc.

JAMES L. ROBO

James L. Robo

Chairman, President and Chief Executive Officer and Director

(Principal Executive Officer)

Date: February 17, 2022

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.

Signature and Title as of February 17, 2022:

REBECCA J. KUJAWA	JAMES M. MAY
Rebecca J. Kujawa Executive Vice President, Finance and Chief Financial Officer (Principal Financial Officer)	James M. May Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer)

Directors:

SHERRY S. BARRAT	DAVID L. PORGES
Sherry S. Barrat	David L. Porges
JAMES L. CAMAREN	RUDY E. SCHUPP
James L. Camaren	Rudy E. Schupp
KENNETH B. DUNN	JOHN L. SKOLDS
Kenneth B. Dunn	John L. Skolds
NAREN K. GURSAHANEY	LYNN M. UTTER
Naren K. Gursahaney	Lynn M. Utter
KIRK S. HACHIGIAN	DARRYL L. WILSON
Kirk S. Hachigian	Darryl L. Wilson
AMY B. LANE
Amy B. Lane

123

FLORIDA POWER & LIGHT COMPANY SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized and in the capacities and on the date indicated.

Florida Power & Light Company

ERIC E. SILAGY

Eric E. Silagy

President and Chief Executive Officer and Director

(Principal Executive Officer)

Date: February 17, 2022

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.

Signature and Title as of February 17, 2022:

REBECCA J. KUJAWA	KEITH FERGUSON
Rebecca J. Kujawa Executive Vice President, Finance and Chief Financial Officer and Director (Principal Financial Officer)	Keith Ferguson Controller (Principal Accounting Officer)

Director:

JAMES L. ROBO

James L. Robo

Supplemental Information to be Furnished With Reports Filed Pursuant to Section 15(d) of the Securities Exchange Act of 1934 by Registrants Which Have Not Registered Securities Pursuant to Section 12 of the Securities Exchange Act of 1934

No annual report, proxy statement, form of proxy or other proxy soliciting material has been sent to security holders of FPL during the period covered by this Annual Report on Form 10-K for the fiscal year ended December 31, 2021.

124

EX-4.AAA

Exhibit 4(aaa)

Description of Securities
Registered Pursuant to Section 12
of the Securities Exchange Act of 1934

As of January 1, 2022 (“Description Date”), (a) NextEra Energy, Inc. (“NEE”) had four classes of securities registered under Section 12 of the Securities Exchange Act of 1934: (i) common stock, $.01 par value per share (“common stock”), (ii) 4.872% Corporate Units (“4.872% Corporate Units”), (iii) 5.279% Corporate Units (“5.279% Corporate Units”) and (iv) 6.219% Corporate Units (“6.219% Corporate Units”) and (b) NextEra Energy Capital Holdings, Inc. (“NEE Capital”) had one class of securities registered under Section 12 of the Exchange Act—its Series N Junior Subordinated Debentures due March 1, 2079 (“Series N Junior Subordinated Debentures”). The common stock is listed on The New York Stock Exchange (“NYSE”) under the symbol “NEE”, the 4.872% Corporate Units are listed on the NYSE under the symbol “NEE.PRO”, the 5.279% Corporate Units are listed on the NYSE under the symbol “NEE.PRP”, the 6.219% Corporate Units are listed on the NYSE under the symbol “NEE.PRQ”, and the Series N Junior Subordinated Debentures are listed on the NYSE under the symbol “NEE.PRN.”

The following description is as of the Description Date, unless otherwise noted.

INDEX

Page

I.    Common Stock

Description of Common Stock    1

II.    Corporate Units

Description of the Equity Units    6

Description of the Purchase Contracts    14

Certain Other Provisions of the Purchase Contract Agreements and the Pledge Agreements    34

Description of the NEE Capital Debentures    39

Description of NEE Guarantee    54

United States Federal Income Tax Discussion    56

III.    Junior Subordinated Debentures

Description of the NEE Capital Junior Subordinated Debentures and NEE Junior
Subordinated Guarantee    69

IV.    Trustee

Information Concerning the Trustee    87

I. COMMON STOCK

DESCRIPTION OF COMMON STOCK

The following is a summary description of the terms of the common stock of NEE. The description is qualified in its entirety by reference to the provisions of NEE’s Restated Articles of Incorporation (the “Charter”) and the Amended and Restated Bylaws (“Bylaws”) as in effect on the Description Date, as well as provisions of the Florida Business Corporation Act (“Florida Act”) and other applicable laws. Copies of the Charter and Bylaws have been filed by NEE with the Securities and Exchange Commission (“SEC”) and are exhibits to the NEE’s Annual Report on Form 10-K to which this Description of Securities Registered Pursuant to Section 12 of the Securities Exchange Act of 1934 is an exhibit (“Form 10-K”).

Authorized and Outstanding Capital Stock

NEE’s Charter authorizes it to issue 3,300,000,000 shares of capital stock, each with a par value of $.01, consisting of:

•3,200,000,000 shares of common stock; and

•100,000,000 shares of preferred stock.

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As of January 31, 2022, there were 1,962,744,998 shares of common stock and no shares of preferred stock outstanding.

Common Stock Terms

Voting Rights. In general, each holder of common stock is entitled to one vote for each share held by such holder on all matters submitted to a vote of holders of common stock, including the election of directors. Each holder of common stock is entitled to attend all special and annual meetings of NEE’s shareholders. The holders of common stock do not have cumulative voting rights.

In general, if a quorum exists at a meeting of NEE’s shareholders, unless a greater or different vote is required by the Florida Act, NEE’s Charter or NEE’s Bylaws, or by action of the board of directors, (1) on all matters other than the election of directors, action on such matters will be approved if the votes cast favoring the action exceed the votes cast opposing the action, (2) in an uncontested director election, a nominee for director will be elected if the votes cast for the nominee’s election exceed the votes cast against the nominee’s election, and (3) in a contested director election, which is an election in which the number of persons considered for election to the board of directors exceeds the total number of directors to be elected, a nominee for director will be elected by a plurality of the votes cast. Other voting rights of shareholders are described below under “—Anti-Takeover Effects of Provisions in NEE’s Charter and NEE’s Bylaws.”

Dividend Rights. The holders of common stock are entitled to participate on an equal per share basis in any dividends declared on the common stock by NEE’s board of directors out of funds legally available for dividend payments.

The declaration and payment of dividends on the common stock is within the sole discretion of NEE’s board of directors. NEE’s Charter does not limit the dividends that may be paid on the common stock.

The ability of NEE to pay dividends on the common stock is currently subject to, and in the future may be limited by:

•various risks which affect the businesses of Florida Power & Light Company (“FPL”) and NEE’s other subsidiaries that may in certain instances limit the ability of such subsidiaries to pay dividends to NEE; and

•various contractual restrictions applicable to NEE and some of its subsidiaries, including those described below.

FPL is subject to the terms of its Mortgage and Deed of Trust dated as of January 1, 1944, with Deutsche Bank Trust Company Americas, as mortgage trustee, as amended and supplemented from time to time (the “FPL Mortgage”), that secures its obligations under outstanding first mortgage bonds issued by it from time to time. In specified circumstances, the terms of the FPL Mortgage could restrict the amount of retained earnings that FPL can use to pay cash dividends on its common stock. As of the Description Date, no retained earnings were restricted by these provisions of the FPL Mortgage.

Other contractual restrictions on the dividend-paying ability of NEE and its subsidiaries are contained in outstanding financing arrangements, and similar or other restrictions may be included in future financing arrangements. As of the Description Date, NEE has equity units outstanding. In accordance with the terms of the equity units, NEE has the right, from time to time, to defer the payment of contract adjustment payments on the purchase contracts that form a part of the equity units to a date no later than the applicable Purchase Contract Settlement Date. As of the Description Date, a subsidiary of NEE, NEE Capital, has junior subordinated debentures outstanding. In accordance with the terms of the junior subordinated debentures NEE Capital has the right, from time to time, to defer the payment of interest on its outstanding junior subordinated debentures on one or more occasions for up to ten consecutive years. NEE, FPL and NEE Capital may issue, from time to time, additional equity units, junior subordinated debentures or other securities that (i) provide them with rights to defer the payment of interest or other payments and (ii) contain dividend restrictions in the event of the exercise of such rights. In the

2

DB1/ 126707718.2

event that NEE or NEE Capital were to exercise any right to defer interest or other payments on currently outstanding or future series of equity units, junior subordinated debentures or other securities, or if there were to occur certain payment defaults on those securities, NEE would not be able, with limited exceptions, to pay dividends on the common stock during the periods in which such payments were deferred or such payment defaults continued. In the event that FPL was to issue equity units, junior subordinated debentures or other securities having similar provisions and was to exercise any such right to defer the payment of interest or other payments on such securities, or if there was to occur certain payment defaults on those securities, FPL would not be able, with limited exceptions, to pay dividends to NEE or any other holder of its common stock or preferred stock during the periods in which such payments were deferred or such payment defaults continued. In addition, NEE, NEE Capital and FPL might issue other securities in the future containing similar or other restrictions on, or that affect, NEE’s ability to pay dividends on its common stock and on the ability of NEE’s subsidiaries, including NEE Capital and FPL, to pay dividends to any holder of their respective common stock or preferred stock, including NEE.

In addition, the right of the holders of NEE’s common stock to receive dividends might become subject to the preferential dividend, redemption, sinking fund or other rights of the holders of any series of NEE preferred stock that may be issued in the future, and the right of the holders (including NEE) of FPL or NEE Capital, as the case may be, common stock or preferred stock, as the case may be, to receive dividends might become subject to the preferential dividend, redemption, sinking fund or other rights of the holders of any series of FPL or NEE Capital, as the case may be, preferred stock that may be issued in the future.

Liquidation Rights. If there is a liquidation, dissolution or winding up of NEE, the holders of common stock are entitled to share equally and ratably in any assets remaining after NEE has paid, or provided for the payment of, all of its debts and other liabilities, and after NEE has paid, or provided for the payment of, any preferential amounts payable to the holders of any outstanding preferred stock.

Other Rights. The holders of common stock do not have any preemptive, subscription, conversion or sinking fund rights. The common stock is not subject to redemption.

Anti-Takeover Effects of Provisions in NEE’s Charter and NEE’s Bylaws

NEE’s Charter and NEE’s Bylaws contain provisions that may make it difficult and expensive for a third party to pursue a takeover attempt that NEE’s board of directors and management oppose even if a change in control of NEE might be beneficial to the interests of holders of common stock.

NEE’s Charter Provisions. Among NEE’s Charter provisions that could have an anti-takeover effect are those that:

•provide that a vacancy on the board of directors may be filled only by a majority vote of the remaining directors;

•prohibit the shareholders from taking action by written consent in lieu of a meeting of shareholders;

•limit the persons who may call a special meeting of shareholders to the chairman of the NEE board of directors, the president or the secretary, a majority of the board of directors or the holders of 20% of the outstanding shares of stock entitled to vote on the matter or matters to be presented at the meeting;

•require any action by shareholders to amend or repeal NEE’s Bylaws, or to adopt new bylaws, to receive the affirmative vote of holders of at least a majority of the voting power of the outstanding shares of voting stock, voting together as a single class; and

•require the affirmative vote of holders of at least a majority of the voting power of the outstanding shares of voting stock, voting together as a single class, to alter, amend or repeal specified provisions of NEE’s Charter, including the foregoing provisions.

3

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NEE’s Bylaw Provisions. NEE’s Bylaws contain some of the foregoing provisions contained in NEE’s Charter. NEE’s Bylaws also contain a provision limiting to 16 directors the maximum number of authorized directors of NEE. In addition, NEE’s Bylaws contain provisions that establish advance notice requirements for shareholders to nominate candidates for election as directors at any annual or special meeting of shareholders or to present any other business for consideration at any annual meeting of shareholders. These provisions generally require a shareholder to submit in writing to NEE’s secretary any nomination of a candidate for election to the board of directors or any other proposal for consideration at any annual meeting not earlier than 120 days or later than 90 days before the first anniversary of the preceding year’s annual meeting. NEE’s Bylaws also require a shareholder to submit in writing to NEE’s secretary any nomination of a candidate for election to the board of directors for consideration at any special meeting not earlier than 120 days before such special meeting and not after the later of 90 days before such special meeting or the tenth day following the day of the first public announcement of the date of the special meeting and of the fact that directors are to be elected at the meeting. For the shareholder’s notice to be in proper form, it must include all of the information specified in NEE’s Bylaws.

Preferred Stock. The rights and privileges of holders of common stock may be adversely affected by the rights, privileges and preferences of holders of shares of any series of preferred stock which NEE’s board of directors may authorize for issuance from time to time. NEE’s board of directors has broad discretion with respect to the creation and issuance of any series of preferred stock without shareholder approval, subject to any applicable rights of holders of any shares of preferred stock outstanding at any time. In that regard, NEE’s Charter authorizes NEE’s board of directors from time to time and without shareholder action to provide for the issuance of up to 100,000,000 shares of preferred stock in one or more series, and to determine the designations, preferences, limitations and relative or other rights of any such series, including voting rights, dividend rights, liquidation preferences, sinking fund provisions, conversion privileges and redemption rights. Among other things, by authorizing the issuance of shares of preferred stock with particular voting, conversion or other rights, the board of directors could adversely affect the voting power of the holders of common stock and could discourage any attempt to effect a change in control of NEE, even if such a transaction would be beneficial to the interests of holders of common stock.

Restrictions on Affiliated and Control Share Transactions under Florida Act

Affiliated Transactions. As a Florida corporation, NEE is subject to the Florida Act, which provides that a Florida corporation generally may not engage in an “affiliated transaction” with an “interested shareholder,” as those terms are defined in the statute, for three years following the date a shareholder becomes an “interested shareholder,” unless:

•prior to the time that such shareholder became an interested shareholder, the board of directors approved either the affiliated transaction or the transaction which resulted in the shareholder becoming an interested shareholder,

•upon consummation of the transaction that resulted in the shareholder becoming an interested shareholder, the interested shareholder owned at least 85 percent of the voting shares of the corporation outstanding at the time the transaction commenced, subject to certain exclusions, or

•at or subsequent to the time that such shareholder became an interested shareholder, the affiliated transaction is approved by the board of directors and authorized by the affirmative vote of at least two-thirds of the outstanding voting shares which are not owned by the interested shareholder.

The Florida Act generally defines an “interested shareholder” as any person who is the beneficial owner of more than 15% of the outstanding voting shares of the corporation. The affiliated transactions covered by the Florida Act include, with specified exceptions:

•mergers and consolidations to which the corporation and the interested shareholder are parties,

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•sales or certain other dispositions of assets representing 10% or more of the aggregate fair market value of the corporation’s assets, outstanding shares, earning power or net income to the interested shareholder,

•generally, issuances by the corporation of 10% or more of the aggregate fair market value of its outstanding shares to the interested shareholder,

•the adoption of any plan for the liquidation or dissolution of the corporation proposed by or pursuant to an arrangement with the interested shareholder,

•any reclassification of the corporation’s securities, recapitalization of the corporation, merger or consolidation, or other transaction which has the effect of increasing by more than 10% the percentage of the outstanding voting shares of the corporation beneficially owned by the interested shareholder, and

•the receipt by the interested shareholder of certain loans or other financial assistance from the corporation.

The foregoing transactions generally also include transactions involving any affiliate of the interested shareholder and involving or affecting any direct or indirect majority-owned subsidiary of the corporation.

The voting requirements above will not apply if, among other things, subject to specified qualifications:

•the transaction has been approved by a majority of the corporation’s disinterested directors,

•the interested shareholder has been the beneficial owner of at least 80% of the corporation’s outstanding voting shares for at least three years preceding the transaction,

•the interested shareholder is the beneficial owner of at least 90% of the outstanding voting shares, or

•specified fair price and procedural requirements are satisfied.

Control-Share Acquisitions. The Florida Act also contains a control-share acquisition statute which provides that a person who acquires shares in an “issuing public corporation,” as defined in the statute, in excess of certain specified thresholds generally will not have any voting rights with respect to such shares unless such voting rights are approved by the holders of a majority of the votes of each class of securities entitled to vote separately, excluding shares held or controlled by the acquiring person. The thresholds specified in the Florida Act are the acquisition of a number of shares representing:

•one-fifth or more, but less than one-third, of all voting power of the corporation,

•one-third or more, but less than a majority, of all voting power of the corporation, or

•a majority or more of all voting power of the corporation.

The statute does not apply if, among other things, the acquisition:

•is approved by the corporation’s board of directors, or

•is effected pursuant to a statutory merger or share exchange to which the corporation is a party.

The statute also does not apply to an acquisition of shares of a corporation in excess of a specified threshold if, before the acquisition, the corporation’s articles of incorporation or bylaws provide that the corporation will not be governed by the statute. The statute also permits a corporation to adopt a provision in its articles of incorporation

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or bylaws providing for the redemption of the acquired shares by the corporation in specified circumstances. NEE’s Charter and NEE’s Bylaws do not contain such provisions.

Indemnification

Florida law generally provides that a Florida corporation, such as NEE, may indemnify its directors and officers against liabilities and expenses they may incur. Florida law also limits the liability of directors to NEE and other persons. NEE’s Bylaws contain provisions requiring NEE to indemnify its directors, officers, employees and agents under specified conditions. In addition, NEE carries insurance permitted by the laws of Florida on behalf of its directors, officers, employees and agents.

Shareholder Access

NEE’s Bylaws permit a shareholder, or a group of up to 20 shareholders, owning continuously for at least three years 3% or more of NEE’s outstanding common stock (an “eligible shareholder”) to nominate and include in NEE’s annual meeting proxy materials director candidates to occupy (together with any nominees of other eligible shareholders) up to two or 20% of the number of directors in office (whichever is greater), provided that such eligible shareholder satisfies the requirements set forth in NEE’s Bylaws. Those requirements generally include receipt by NEE’s secretary of written notice from an eligible shareholder of the nomination not earlier than 150 days or later than 120 days before the first anniversary of the mailing of NEE’s proxy materials for the most recent annual meeting. For the eligible shareholder’s notice to be in proper form, it must include all of the information specified in NEE’s Bylaws.

Transfer Agent and Registrar

The transfer agent and registrar for the common stock is Computershare Trust Company, N.A.

II.    CORPORATE UNITS

DESCRIPTION OF THE EQUITY UNITS

NEE has issued three series of equity units, as described in the following paragraph, which are currently outstanding. NEE entered into a separate purchase contract agreement, pledge agreement and remarketing agreement with respect to each series of equity units. In addition, NEE Capital issued a different series of debentures, as described below, in connection with each issuance of equity units. References in this section to the foregoing agreements refer to the corresponding agreements that were entered into in connection with such equity unit transactions. In addition, certain terms are defined in Annex A and reference is made to such Annex A.

NEE has issued

•Equity Units (“2019 Equity Units”) under a purchase contract agreement, dated as of September 1, 2019 (“2019 purchase contract agreement”),

•Equity Units (“February 2020 Equity Units”) under a purchase contract agreement, dated as of February 1, 2020 (“February 2020 purchase contract agreement”),

•Equity Units (“September 2020 Equity Units” and together with the 2019 Equity Units and the February 2020 Equity Units, the “Equity Units”) under a purchase contract agreement, dated as of September 1, 2020 (“September 2020 purchase contract agreement,” and together with the 2019 purchase contract agreement and the February 2020 purchase contract agreement, each a “purchase contract agreement”, and collectively, the “purchase contract agreements”),

each between NEE and The Bank of New York Mellon, as purchase contract agent (“purchase contract agent”). The 2019 Equity Units initially consisted of 30,000,000 4.872% Corporate Units, the February 2020 Equity Units initially consisted of 50,000,000 5.279% Corporate Units and the September 2020 Equity Units initially consisted of

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40,000,000 6.219% Corporate Units (the 6.219% Corporate Units, together with the 4.872% Corporate Units and the 5.279% Corporate Units, the “Corporate Units”). This section briefly summarizes some of the terms of the Equity Units, including the Corporate Units, and some of the provisions of the respective purchase contract agreements and

•a pledge agreement, dated as of September 1, 2019 (“2019 pledge agreement”) with respect to the 2019 Equity Units,

•a pledge agreement, dated as of February 1, 2020 (“February 2020 pledge agreement”) with respect to the February 2020 Equity Units and

•a pledge agreement, dated as of September 1, 2020 (“September 2020 pledge agreement” and together with the 2019 pledge agreement and the February 2020 pledge agreement, each a “pledge agreement”, and collectively the “pledge agreements”) with respect to the September 2020 Equity Units,

in each case between NEE, Deutsche Bank Trust Company Americas, as collateral agent, custodial agent and securities intermediary (“collateral agent”), and The Bank of New York Mellon, as purchase contract agent. This summary does not contain a complete description of the Equity Units. You should read this summary together with the respective purchase contract agreement and the respective pledge agreement for a complete understanding of all the provisions and for the definitions of some terms used in this summary. The purchase contract agreements and the pledge agreements have been filed by NEE with the SEC and are exhibits to the Form 10-K. In addition, each purchase contract agreement is qualified under the Trust Indenture Act of 1939 and is therefore subject to the provisions of the Trust Indenture Act of 1939. You should read the Trust Indenture Act of 1939 for a complete understanding of its provisions.

General

The 2019 Equity Units initially consisted of 30,000,000 Corporate Units, the February 2020 Equity Units initially consisted of 50,000,000 Corporate Units and the September 2020 Equity Units initially consisted of 40,000,000, in each case with a stated amount of $50.

Each Corporate Unit consists of a unit comprised of:

•a purchase contract, pursuant to which

•the holder agrees to purchase from NEE, and NEE agrees to sell to the holder, not later than the Purchase Contract Settlement Date (as defined in Annex A), or upon early settlement, for $50, a number of newly issued shares of NEE common stock equal to the applicable settlement rate described below under “Description of the Purchase Contracts—Purchase of NEE Common Stock,” “Description of the Purchase Contracts—Early Settlement by Delivering Cash,” and “Description of the Purchase Contracts—Early Settlement upon a Fundamental Change,” and

•NEE will make contract adjustment payments to the holder at the Contract Adjustment Rate (as defined in Annex A) per year on the stated amount of $50, or the Contract Adjustment Annualized Amount (as defined in Annex A) per year, payable quarterly, and subject to NEE’s right to defer these payments,

•and either

•a 5% applicable ownership interest in a NEE Capital Related Debenture (as defined in Annex A, and herein referred to as, a “NEE Capital debenture” and collectively, “NEE Capital debentures”) in the principal amount of $1,000 under which NEE Capital will pay to the holder 5% of the interest payment on a debenture in the principal amount of $1,000 at the initial rate of the Initial Interest Rate (as defined in Annex A) per year (resulting in a payment of the Initial Interest Annualized Amount (as defined in Annex A) per year), or

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•following a successful remarketing of the NEE Capital debentures on or prior to the ninth business day preceding the Purchase Contract Settlement Date, or the occurrence of a special event redemption or a mandatory redemption, the applicable ownership interest in a portfolio of U.S. Treasury securities maturing on or prior to the Treasury Portfolio Maturity Deadline (as defined in Annex A), which is referred to as the “Treasury portfolio.”

“Applicable ownership interest” means with respect to the U.S. Treasury securities in the Treasury portfolio:

•for a remarketing Treasury portfolio,

•a 5% undivided beneficial ownership interest in $1,000 face amount of U.S. Treasury securities (or principal or interest strips thereof) included in the Treasury portfolio that mature on or prior to the Treasury Portfolio Maturity Deadline,

•if the “reset effective date” (which means, in the case of a successful remarketing during the period for early remarketing, the third business day immediately following the date of the successful remarketing, unless the remarketing is successful within five business days of the next succeeding interest payment date in which case the reset effective date will be such interest payment date, and, in the case of a successful remarketing during the final three-day remarketing period, the purchase contract settlement date) occurs prior to the Three Month Date (as defined in Annex A), with respect to the originally-scheduled quarterly interest payment dates on the NEE Capital debentures that would have occurred on the Three Month Date and the Purchase Contract Settlement Date, an undivided beneficial ownership interest in a $1,000 face amount of U.S. Treasury securities (or principal or interest strips thereof) that mature on or prior to (i) the Day Before the Three Month Date (as defined in Annex A) (in connection with the interest payment date that would have occurred on the Three Month Date) and (ii) the Treasury Portfolio Maturity Deadline (in connection with the interest payment date that would have occurred on the Purchase Contract Settlement Date), each in an aggregate amount at maturity equal to the aggregate interest payments that would be due on the Three Month Date and the Purchase Contract Settlement Date, respectively, with respect to a 5% beneficial ownership interest in a NEE Capital debenture in the principal amount of $1,000 that would have been components of the Corporate Units assuming no remarketing and no reset of the interest rate on the NEE Capital debentures as described under “Description of the NEE Capital Debentures—Market Reset Rate” and assuming that interest on the NEE Capital debentures accrued from the reset effective date to, but excluding, the Three Month Date and from the Three Month Date to, but excluding, the Purchase Contract Settlement Date, respectively, and

•if the reset effective date occurs on or after the Three Month Date, with respect to the originally-scheduled quarterly interest payment date on the NEE Capital debentures that would have occurred on the Purchase Contract Settlement Date, an undivided beneficial ownership interest in a $1,000 face amount of U.S. Treasury securities (or principal or interest strips thereof) that mature on or prior to the Treasury Portfolio Maturity Deadline in an aggregate amount at maturity equal to the aggregate interest payment that would be due on the Purchase Contract Settlement Date with respect to a 5% beneficial ownership interest in a NEE Capital debenture in the principal amount of $1,000 that would have been components of the Corporate Units assuming no remarketing and no reset of the interest rate on the NEE Capital debentures and assuming that interest on the NEE Capital debentures accrued from the reset effective date to, but excluding, the Purchase Contract Settlement Date.

If U.S. Treasury securities (or principal or interest strips thereof) that are to be included in the remarketing Treasury portfolio have a yield that is less than zero, then instead, at NEE Capital’s option, the remarketing Treasury portfolio will consist of an amount in cash equal to the aggregate principal amount at maturity of the applicable U.S. Treasury securities (or

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principal or interest strips thereof) described above. If the provisions set forth in this paragraph apply, references to “U.S. Treasury securities (or principal or interest strips thereof)” in connection with the remarketing Treasury portfolio will, thereafter, be deemed to be references to such amount of cash.

•for a special event Treasury portfolio,

•a 5% undivided beneficial ownership interest in $1,000 face amount of U.S. Treasury securities (or principal or interest strips thereof) included in the Treasury portfolio that mature on or prior to the Treasury Portfolio Maturity Deadline, and

•with respect to each scheduled interest payment date on the NEE Capital debentures that would have occurred after the special event redemption date and on or prior to the Purchase Contract Settlement Date, an undivided beneficial ownership interest in a $1,000 face amount of U.S. Treasury securities (or principal or interest strips thereof) that mature on or prior to that interest payment date in an aggregate amount equal to the aggregate interest payment that would be due with respect to a 5% beneficial ownership interest in a NEE Capital debenture in the principal amount of $1,000 that would have been components of the Corporate Units on that date (assuming no special event redemption) and accruing from and including the immediately preceding interest payment date to which interest has been paid.

If a Treasury portfolio is required to be purchased in connection with a mandatory redemption of NEE Capital debentures, an applicable ownership interest in such Treasury portfolio will be the same as an applicable ownership interest in a special event Treasury portfolio.

For U.S. federal income tax purposes, the purchase price of each Corporate Unit was allocated between the related purchase contract and the applicable ownership interest in a NEE Capital debenture in proportion to their respective fair market values at the time of issuance. NEE will report the fair market value of the 5% applicable ownership interest in a $1,000 principal amount of each NEE Capital debenture as the NEE Capital Debenture Fair Market Value (as defined in Annex A), and NEE Capital will report the fair market value of each purchase contract as $0. This position generally will be binding on each beneficial owner of each Corporate Unit, but not on the Internal Revenue Service (“IRS”). See “United States Federal Income Tax Discussion—U.S. Holders—Allocation of Purchase Price.”

As long as an Equity Unit is in the form of a Corporate Unit, the related applicable ownership interest in a NEE Capital debenture or the applicable ownership interest in a Treasury portfolio, as applicable, that is a component of the Corporate Unit will be pledged to NEE through the collateral agent to secure the holder’s obligation to purchase NEE common stock under the related purchase contract.

Creating Treasury Units by Substituting a Treasury Security for a NEE Capital Debenture

Unless the Treasury portfolio has replaced the NEE Capital debentures as a component of the Corporate Units as a result of a successful remarketing, a special event redemption or a mandatory redemption, each holder of Corporate Units has the right, on or prior to the seventh business day immediately preceding the Purchase Contract Settlement Date, to substitute for the related NEE Capital debentures held by the collateral agent a zero-coupon U.S. Treasury security (Zero-Coupon CUSIP (as defined in Annex A)) maturing on the Treasury Portfolio Maturity Deadline, having a principal amount at maturity equal to the aggregate principal amount of the NEE Capital debentures for which substitution is being made. These substitutions will create Treasury Units, and the NEE Capital debentures will be released to the holder. Because Treasury securities and NEE Capital debentures are issued in integral multiples of $1,000, holders of Corporate Units may make these substitutions only in integral multiples of 20 Corporate Units.

The ability of holders of Corporate Units to create Treasury Units is subject to the limitation that holders may not create Treasury Units during any period commencing on and including the business day prior to the first day of any three-day remarketing period and ending on and including, in the case of a successful remarketing during

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that three-day remarketing period, the reset effective date, or, if none of the remarketings during that three-day remarketing period is successful, the business day following the last remarketing date in the applicable three-day remarketing period.

If a Treasury portfolio has replaced the NEE Capital debentures as a component of the Corporate Units as a result of a successful remarketing of the NEE Capital debentures, a special event redemption or a mandatory redemption, each holder of Corporate Units may create Treasury Units by making substitutions of Treasury securities for the applicable ownership interest in the Treasury portfolio, on or prior to the second business day immediately preceding the Purchase Contract Settlement Date and only in integral multiples of the Minimum Number (as defined in Annex A) of Corporate Units (or such other number of Corporate Units as may be determined by the remarketing agents upon a successful remarketing of the NEE Capital debentures if the reset effective date is not a regular quarterly interest payment date). In such a case, the holder would also obtain the release of the applicable ownership interest in the Treasury portfolio rather than a release of the NEE Capital debentures.

Each Treasury Unit will consist of a unit with a stated amount of $50, comprised of:

•a purchase contract, pursuant to which

•the holder will agree to purchase from NEE, and NEE will agree to sell to the holder, not later than the Purchase Contract Settlement Date, or upon early settlement, for $50, a number of newly issued shares of NEE common stock equal to the applicable settlement rate described below under “Description of the Purchase Contracts—Purchase of NEE Common Stock,” “Description of the Purchase Contracts—Early Settlement by Delivering Cash,” and “Description of the Purchase Contracts—Early Settlement upon a Fundamental Change,” and

•NEE will make contract adjustment payments to the holder at the Contract Adjustment Rate per year on the stated amount of $50, or the Contract Adjustment Annualized Amount per year, payable quarterly, and subject to NEE’s right to defer these payments, and

•a 5% undivided beneficial ownership interest in a Treasury security having a principal amount at maturity of $1,000.

Unless the Treasury portfolio has replaced the NEE Capital debentures as a component of the Corporate Units, to create 20 Treasury Units the Corporate Unit holder will:

•deposit with the collateral agent a Treasury security having a principal amount at maturity of $1,000, which Treasury security must have been purchased in the open market at the holder’s expense, unless otherwise owned by the holder; and

•transfer 20 Corporate Units to the purchase contract agent accompanied by a notice stating that the holder has deposited a Treasury security in the required amount with the collateral agent and requesting that the purchase contract agent instruct the collateral agent to release the related NEE Capital debenture.

Upon that deposit and the receipt of an instruction from the purchase contract agent, the collateral agent will release the related NEE Capital debenture from the pledge under the applicable pledge agreement and deliver it to the purchase contract agent, on behalf of the holder, free and clear of NEE’s security interest. The purchase contract agent then will:

•cancel the 20 Corporate Units;

•transfer the related NEE Capital debenture to the holder; and

•deliver 20 Treasury Units to the holder.

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The Treasury security will be substituted for the NEE Capital debenture and will be pledged to NEE through the collateral agent to secure the holder’s obligation to purchase NEE common stock under the related purchase contract. The related NEE Capital debenture released to the holder thereafter will trade separately from the resulting Treasury Units.

If the Treasury portfolio has replaced the NEE Capital debentures as a component of the Corporate Units, then to create Treasury Units the Corporate Unit holder will have the right to substitute Treasury securities for the applicable ownership interests in the Treasury portfolio by following the same procedure specified above for creating a Treasury Unit, except the holder will have to deposit integral multiples of the Minimum Number of Corporate Units (or such other number of Corporate Units as may be determined by the remarketing agents upon a successful remarketing of the NEE Capital debentures if the reset effective date is not a regular quarterly interest payment date).

Holders that elect to substitute pledged securities, thereby creating Treasury Units or recreating Corporate Units, will be responsible for any fees or expenses payable in connection with the substitution. See “Certain Other Provisions of the Purchase Contract Agreements and the Pledge Agreements—Miscellaneous.”

Recreating Corporate Units

Unless the Treasury portfolio has replaced the NEE Capital debentures as a component of the Corporate Units as a result of a successful remarketing, a special event redemption or a mandatory redemption, each holder of Treasury Units will have the right, on or prior to the second business day immediately preceding the first day of the final three-day remarketing period, to substitute NEE Capital debentures for any related Treasury securities held by the collateral agent, having a principal amount equal to the aggregate principal amount of the Treasury securities at maturity for which substitution is being made. These substitutions will recreate Corporate Units, and the Treasury securities will be released to the holder. Because Treasury securities and NEE Capital debentures are issued in integral multiples of $1,000, holders of Treasury Units may make these substitutions only in integral multiples of 20 Treasury Units.

The ability of holders of Treasury Units to recreate Corporate Units will be subject to the limitation that holders may not recreate Corporate Units during any period commencing on and including the business day prior to the first day of any three-day remarketing period and ending on and including, in the case of a successful remarketing during that three-day remarketing period, the reset effective date, or, if none of the remarketings during that three-day remarketing period is successful, the business day following the last remarketing date in the applicable three-day remarketing period.

If a Treasury portfolio has replaced the NEE Capital debentures as a component of the Corporate Units as a result of a successful remarketing of the NEE Capital debentures, a special event redemption or a mandatory redemption, each holder of Treasury Units may recreate Corporate Units by making substitutions of the applicable ownership interest in the Treasury portfolio for the Treasury securities, on or prior to the second business day immediately preceding the Purchase Contract Settlement Date and only in integral multiples of the Minimum Number of Treasury Units (or such other number of Treasury Units as may be determined by the remarketing agents in connection with a successful remarketing of the NEE Capital debentures if the reset effective date is not a regular quarterly interest payment date). In such a case, the holder would also obtain the release of the Treasury securities for which substitution is being made.

Unless the Treasury portfolio has replaced the NEE Capital debentures as a component of the Corporate Units, to recreate 20 Corporate Units a Treasury Unit holder will:

•deposit with the collateral agent a NEE Capital debenture in the principal amount of $1,000, which NEE Capital debenture must have been purchased in the open market at the holder’s expense, unless otherwise owned by the holder; and

•transfer 20 Treasury Units to the purchase contract agent accompanied by a notice stating that the holder has deposited a NEE Capital debenture in the principal amount of $1,000 with the collateral

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agent and requesting that the purchase contract agent instruct the collateral agent to release the related Treasury security.

Upon that deposit and the receipt of an instruction from the purchase contract agent, the collateral agent will release the related Treasury security from the pledge under the applicable pledge agreement and deliver it to the purchase contract agent, on behalf of the holder, free and clear of NEE’s security interest. The purchase contract agent will then:

•cancel the 20 Treasury Units;

•transfer the related Treasury security to the holder; and

•deliver 20 Corporate Units to the holder.

The NEE Capital debenture will be substituted for the Treasury security and will be pledged to NEE through the collateral agent to secure the holder’s obligation to purchase NEE common stock under the related purchase contract.

If the Treasury portfolio has replaced the NEE Capital debentures as a component of the Corporate Units, the Treasury Unit holder will follow the same procedure specified above for recreating Corporate Units, except that the holder will have to deposit integral multiples of the Minimum Number of Treasury Units and must deposit integral multiples of the Minimum Number of applicable ownership interests in the Treasury portfolio with the collateral agent, which must be purchased in the open market at the expense of the Treasury Unit holder, unless otherwise owned by the holder.

Holders that elect to substitute pledged securities, thereby creating Treasury Units or recreating Corporate Units, will be responsible for any fees or expenses payable in connection with the substitution. See “Certain Other Provisions of the Purchase Contract Agreements and the Pledge Agreements—Miscellaneous.”

Payments on Corporate Units and Treasury Units

Holders of Corporate Units will be entitled to receive aggregate cash payments at the Corporate Unit Aggregate Rate (as defined in Annex A) per year on the $50 stated amount per Corporate Unit, payable quarterly in arrears. The quarterly payments on the Corporate Units will consist of:

•interest on the related applicable ownership interest in NEE Capital debentures payable by NEE Capital (or cash distributions on the applicable ownership interest in the Treasury portfolio if the NEE Capital debentures have been replaced by the Treasury portfolio), equivalent to the Initial Interest Rate per year on the stated amount; and

•distributions of quarterly contract adjustment payments payable by NEE at the Contract Adjustment Rate per year on the stated amount, subject to NEE’s right to defer the payment of such contract adjustment payments.

If interest on the NEE Capital debentures is reset on a reset effective date that is not a scheduled interest payment date, the collateral agent will receive on behalf of holders of Corporate Units a payment from NEE Capital on the reset effective date of accrued and unpaid interest on the NEE Capital debentures from the most recent quarterly interest payment date to, but excluding, the reset effective date. On the quarterly payment date next following the reset effective date, Corporate Unit holders will receive a quarterly cash distribution comprised of their pro rata portion of that interest payment, the portion of their applicable ownership interest in the remarketing Treasury portfolio that matures prior to that quarterly payment date and the contract adjustment payment payable on that date. If interest on the NEE Capital debentures is reset on a reset effective date that is not a scheduled interest payment date, holders of separate NEE Capital debentures that were not a component of Corporate Units will receive on the reset effective date a payment of accrued and unpaid interest from the most recent quarterly interest payment date to, but excluding, the reset effective date. On the semi-annual interest payment date next following the reset effective

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date, holders of NEE Capital debentures will receive a payment of interest accrued from and including the reset effective date, to, but excluding, such interest payment date.

Holders of Treasury Units will be entitled to receive quarterly cash distributions of contract adjustment payments payable by NEE at the Contract Adjustment Rate per year on the $50 stated amount per Treasury Unit, subject to NEE’s right to defer the payment of such contract adjustment payments. Although holders of Treasury Units will not receive any interest payments on the Treasury securities pledged in connection with the creation of the Treasury Units, the holders of Treasury Units will continue to receive the scheduled interest payments on the NEE Capital debentures that were released to them when the Treasury Units were created for so long as they hold the NEE Capital debentures. Holders of Treasury Units will be required to accrue original issue discount (“OID”) on these Treasury securities.

Ranking

The NEE Capital debentures are senior unsecured obligations of NEE Capital and rank equally in right of payment with all of NEE Capital’s other unsecured and unsubordinated debt obligations. See “Description of the NEE Capital Debentures.”

NEE’s obligations under its guarantee of NEE Capital debentures are senior unsecured obligations of NEE and rank equally in right of payment with all of NEE’s other unsecured and unsubordinated debt obligations. See “Description of NEE Guarantee.”

NEE’s obligations with respect to contract adjustment payments are unsecured and subordinate and junior in right of payment to its obligations under any of its senior indebtedness. “Senior indebtedness” with respect to contract adjustment payments means all of NEE’s indebtedness of any kind, existing or incurred in the future, unless the instrument, if any, under which such indebtedness is incurred expressly provides that it is on a parity in right of payment with or subordinate in right of payment to the contract adjustment payments. Senior indebtedness will be entitled to the benefits of the subordination provisions in the purchase contract agreements.

Voting and Certain Other Rights

Holders of purchase contracts that are components of the Corporate Units or Treasury Units, in their capacities as such holders, will have no rights with respect to NEE common stock (including, without limitation, voting rights and rights to receive any dividends or other distributions on NEE common stock).

Trading of the Securities

Each series of Corporate Units is listed on the NYSE. Unless and until substitution has been made as described in “—Creating Treasury Units by Substituting a Treasury Security for a NEE Capital Debenture” or “—Recreating Corporate Units,” prior to a successful remarketing neither the NEE Capital debentures, nor the applicable ownership interest in the Treasury portfolio component of a Corporate Unit nor the Treasury security component of a Treasury Unit will trade separately from Corporate Units or Treasury Units. The applicable ownership interests in NEE Capital debentures or applicable ownership interest in the Treasury portfolio component will trade as a unit with the purchase contract component of the Corporate Units, and the Treasury security component will trade as a unit with the purchase contract component of the Treasury Units. NEE has no obligation or current intention to apply for listing of the Treasury Units or the NEE Capital debentures. There can be no assurance as to the liquidity of any secondary market for the Corporate Units or that may develop for the Treasury Units or the NEE Capital debentures.

Purchase of Equity Units and NEE Capital Debentures

NEE, its subsidiaries or its affiliates may from time to time, to the extent permitted by law, purchase any of the Corporate Units, Treasury Units or NEE Capital debentures which are then outstanding by tender, in the open market or by private agreement.

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DESCRIPTION OF THE PURCHASE CONTRACTS

This section briefly summarizes some of the terms of the purchase contract agreements, the purchase contracts, the pledge agreements, each remarketing agreement, and the indenture and the officer’s certificates which supplemented the indenture and created the specific terms of the NEE Capital debentures. This summary does not contain a complete description of the purchase contracts. You should read this summary together with the purchase contract agreements, the pledge agreements, the remarketing agreements, the indenture, the officer’s certificates and other documents which established the purchase contracts for a complete understanding of all the provisions and for the definitions of some terms used in this summary. The purchase contract agreements, the purchase contracts, the pledge agreements and the officer’s certificate creating the specific terms of the NEE Capital debentures and the indenture have been previously filed with the SEC and are exhibits to the Form 10-K. In addition, the purchase contract agreements and the indenture are qualified under the Trust Indenture Act of 1939 and are therefore subject to the provisions of the Trust Indenture Act of 1939. You should read the Trust Indenture Act of 1939 for a complete understanding of its provisions.

Purchase of NEE Common Stock

Each purchase contract that is part of a Corporate Unit or a Treasury Unit will obligate its holder to purchase, and NEE to sell, on the Purchase Contract Settlement Date (unless the purchase contract terminates prior to that date or is settled early at the holder’s option), a number of newly issued shares of NEE common stock determined by reference to the “settlement rate,” for $50 in cash. The number of shares of NEE common stock issuable upon settlement of each purchase contractwill be calculated, subject to adjustment under the circumstances described under “—Anti-dilution Adjustments” and “—Early Settlement upon a Fundamental Change,” as follows:

•If the applicable market value of NEE common stock is equal to or greater than the Threshold Appreciation Price (as defined in Annex A), the applicable settlement rate shall equal the Minimum Settlement Rate (as defined in Annex A) of shares of NEE common stock, which is equal to $50 divided by the Threshold Appreciation Price.

Accordingly, if the applicable market value is greater than the Threshold Appreciation Price, the aggregate market value of the shares of NEE common stock issued upon settlement of each purchase contract will be higher than $50, assuming that the market price of NEE common stock on the date of settlement is the same as the applicable market value of NEE common stock. If the market price is the same as the Threshold Appreciation Price, the aggregate market value of those shares of NEE common stock will be equal to $50, assuming that the market price of NEE common stock on the date of settlement is the same as the applicable market value.

•If the applicable market value of NEE common stock is less than the Threshold Appreciation Price but greater than the Reference Price (as defined in Annex A), the applicable settlement rate shall equal the number of shares of NEE common stock equal to $50 divided by the applicable market value.

Accordingly, if the applicable market value is greater than the Reference Price, but the applicable market value does not exceed the Threshold Appreciation Price, the aggregate market value of the shares of NEE common stock issued upon settlement of each purchase contract will be equal to $50, assuming that the market price of NEE common stock on the date of settlement is the same as the applicable market value of NEE common stock.

•If the applicable market value of NEE common stock is less than or equal to the Reference Price, the applicable settlement rate shall equal the Maximum Settlement Rate (as defined in Annex A) of shares of NEE common stock, which is equal to $50 divided by the Reference Price.

Accordingly, if the applicable market value is less than the Reference Price, the aggregate market value of the shares of NEE common stock issued upon settlement of each purchase contract will be less than $50, assuming that the market price of NEE common stock on the date of settlement is the same as the applicable market value of NEE common stock. If the market price is the same as the Reference Price,

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the aggregate market value of those shares of NEE common stock will be equal to $50, assuming that the market price of NEE common stock on the date of settlement is the same as the applicable market value of NEE common stock.

If a holder elects to settle its purchase contract early in the manner described under “—Early Settlement by Delivering Cash,” the number of shares of NEE common stock issuable upon settlement of such purchase contract will be Minimum Settlement Rate, subject to adjustment as described under “—Anti-dilution Adjustments.” The Maximum Settlement Rate and Minimum Settlement Rate are collectively referred to as the “fixed settlement rates.”

“Applicable market value” means the average of the closing price per share of NEE common stock on each of the 20 consecutive trading days ending on the third trading day immediately preceding the Purchase Contract Settlement Date.

“Closing price” of NEE common stock on any date of determination means

•the closing sale price (or, if no closing price is reported, the last reported sale price) of NEE common stock on the NYSE on that date or, if NEE common stock is not listed for trading on the NYSE on any such date, as reported in the composite transactions for the principal United States securities exchange on which NEE common stock is so listed;

•if shares of NEE common stock are not so reported, the last quoted bid price for NEE common stock in the over-the-counter market as reported by OTC Markets Group Inc. or similar organization; or

•if the bid price is not available, the market value of NEE common stock on the date of determination as determined by a nationally recognized independent investment banking firm retained by NEE for this purpose.

A “trading day” means a day on which NEE common stock

•is not suspended from trading on any national or regional securities exchange or over-the-counter market at the close of business, and

•has traded at least once on the national or regional securities exchange or over-the-counter market that is the primary market for the trading of NEE common stock.

If the NEE common stock is not traded on a securities exchange or quoted in the over-the-counter market, then “trading day” shall mean business day.

NEE will not issue any fractional shares of its common stock pursuant to the purchase contracts. In lieu of fractional shares otherwise issuable (calculated on an aggregate basis) in respect of the purchase contracts being settled by a holder of Corporate Units or Treasury Units, the holder will be entitled to receive an amount of cash equal to the fraction of a share multiplied by the applicable market value (or, for an early settlement, by the Threshold Appreciation Price).

Unless:

•a holder of Corporate Units or Treasury Units has early settled the related purchase contracts through the delivery of cash to the purchase contract agent in the manner described under “—Early Settlement by Delivering Cash” or under “—Early Settlement upon a Fundamental Change;”

•a holder of Corporate Units or Treasury Units has settled the related purchase contracts with separate cash pursuant to prior notice given in the manner described under “—Notice to Settle with Cash;” or

•an event described under “—Termination of Purchase Contracts” has occurred,

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then, on the Purchase Contract Settlement Date,

•in the case of Corporate Units, provided that the Treasury portfolio has not replaced the NEE Capital debentures as a component of the Corporate Units as the result of a successful remarketing of the NEE Capital debentures or because a special event redemption or a mandatory redemption has occurred, such holders will be deemed to have elected to apply a portion of the put price equal to the principal amount of the NEE Capital debentures to satisfy in full the holder’s obligation to purchase NEE common stock under the related purchase contracts, and any amount of the put price remaining following settlement of such purchase contracts will be delivered to the purchase contract agent for the benefit of the holder of such Corporate Units; and

•in the case of Treasury Units or, in the event that the Treasury portfolio has replaced the NEE Capital debentures as a component of the Corporate Units as the result of a successful remarketing of the NEE Capital debentures, a special event redemption or a mandatory redemption, in the case of Corporate Units, the principal amount of the related Treasury securities, or the applicable ownership interest in the Treasury portfolio, as applicable, when paid at maturity, will automatically be applied to satisfy in full the holder’s obligation to purchase NEE common stock under the related purchase contract.

NEE common stock will then be issued and delivered to the holder or the holder’s designee, upon presentation and surrender of the certificate evidencing the Equity Units, and payment by the holder of any transfer or similar taxes payable in connection with the issuance of NEE common stock to any person other than the holder.

Each holder of Corporate Units or Treasury Units, by acceptance of those securities, will be deemed to have:

•irrevocably agreed to be bound by the terms and provisions of the Corporate Units and the Treasury Units and to perform such holder’s obligations under the related purchase contract and the related pledge agreement for so long as the holder remains a holder of Equity Units; and

•duly and irrevocably appointed the purchase contract agent as the holder’s attorney-in-fact to enter into and perform the related purchase contracts and the related pledge agreement on behalf of and in the name of the holder.

In addition, each holder and beneficial owner of Corporate Units or Treasury Units, by acceptance of a beneficial interest in those securities, will be deemed to have covenanted and agreed to treat:

•itself as the beneficial owner of the related applicable ownership interest in NEE Capital debentures, the applicable ownership interest in the Treasury portfolio (or, if applicable, cash) or the Treasury securities, as the case may be, and

•the related applicable ownership interest in NEE Capital debentures as indebtedness,

in each case, for all U.S. federal, state and local income, and franchise tax purposes.

So long as the Equity Units are held through the Depositary, the beneficial owners will have rights and obligations with respect to the Equity Units equivalent to those of a holder except exercisable only through the Depositary or its participants. See “—Book-Entry Only System.”

Remarketing

Pursuant to the applicable remarketing agreement, and subject to the terms of the related supplemental remarketing agreement, NEE Capital may, at its option and in its sole discretion, elect to remarket the NEE Capital debentures on any remarketing date occurring during the period for early remarketing beginning on the fifth business day preceding the Six Month Date (as defined in Annex A) and ending on and including the ninth business day preceding the Purchase Contract Settlement Date, unless the NEE Capital debentures have been previously redeemed in connection with a special event redemption or a mandatory redemption or have been previously

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successfully remarketed. Any remarketing during the period for early remarketing will occur during one or more three-day remarketing periods that consist of three sequential possible remarketing days selected by NEE Capital and will include the NEE Capital debentures that are components of the Corporate Units and other separate NEE Capital debentures of holders that have elected to include those NEE Capital debentures in the remarketing.

On each remarketing date occurring during the period for early remarketing, the remarketing agents will use their commercially reasonable efforts to obtain a price for the NEE Capital debentures remarketed equal to or greater than 100% of the remarketing Treasury portfolio purchase price plus the separate NEE Capital debentures purchase price plus the remarketing fee. In no event shall the price for the NEE Capital debentures on each remarketing date, if any, occurring during the period for early remarketing be less than a price equal to 100% of the purchase price for the remarketing Treasury portfolio plus the separate NEE Capital debentures purchase price. The proceeds from the remarketing equal to the remarketing Treasury portfolio purchase price will be applied to purchase, on the reset effective date, a remarketing Treasury portfolio consisting of:

•U.S. Treasury securities (or principal or interest strips thereof) that mature on or prior to the Treasury Portfolio Maturity Deadline in an aggregate amount at maturity equal to the principal amount of the NEE Capital debentures that are components of the Corporate Units;

•if the reset effective date occurs prior to the Three Month Date, with respect to the originally-scheduled quarterly interest payment dates on the NEE Capital debentures that would have occurred on the Three Month Date and the Purchase Contract Settlement Date, U.S. Treasury securities (or principal or interest strips thereof) that mature on or prior to (i) the Day Before the Three Month Date (in connection with the interest payment date that would have occurred on the Three Month Date) and (ii) the Treasury Portfolio Maturity Deadline (in connection with the interest payment date that would have occurred on the Purchase Contract Settlement Date), each in an aggregate amount at maturity equal to the aggregate interest payments that would be due on the Three Month Date and the Purchase Contract Settlement Date, respectively, on the principal amount of the NEE Capital debentures that would have been components of the Corporate Units assuming no remarketing and no reset of the interest rate on the NEE Capital debentures as described under “Description of the NEE Capital Debentures—Market Reset Rate” and assuming that interest on the NEE Capital debentures accrued from the reset effective date to, but excluding, the Three Month Date and from the Three Month Date to, but excluding, the Purchase Contract Settlement Date, respectively; and

•if the reset effective date occurs on or after the Three Month Date, with respect to the originally-scheduled quarterly interest payment date on the NEE Capital debentures that would have occurred on the Purchase Contract Settlement Date, U.S. Treasury securities (or principal or interest strips thereof) that mature on or prior to the Treasury Portfolio Maturity Deadline in an aggregate amount at maturity equal to the aggregate interest payment that would be due on the Purchase Contract Settlement Date on the principal amount of the NEE Capital debentures that would have been components of the Corporate Units assuming no remarketing and no reset of the interest rate on the NEE Capital debentures and assuming that interest on the NEE Capital debentures accrued from the reset effective date to, but excluding, the Purchase Contract Settlement Date.

If U.S. Treasury securities (or principal or interest strips thereof) that are to be included in the remarketing Treasury portfolio have a yield that is less than zero, then instead, at NEE Capital’s option, the remarketing Treasury portfolio will consist of an amount in cash equal to the aggregate principal amount at maturity of the applicable U.S. Treasury securities (or principal or interest strips thereof) described above. If the provisions set forth in this paragraph apply, references to “U.S. Treasury securities (or principal or interest strips thereof)” in connection with the remarketing Treasury portfolio will, thereafter, be deemed to be references to such amount of cash.

The remarketing Treasury portfolio will be substituted for the NEE Capital debentures that are components of the Corporate Units and will be pledged to NEE through the collateral agent to secure the Corporate Unit holders’ obligations to purchase NEE common stock under the related purchase contracts.

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In addition, if a remarketing during the period for early remarketing is successful, the remarketing agents may deduct the remarketing fee from any portion of the proceeds from the remarketing of the NEE Capital debentures that is in excess of the sum of the remarketing Treasury portfolio purchase price and the aggregate separate NEE Capital debentures purchase price, which remarketing fee shall be 25 basis points (0.25%) of the sum of the remarketing Treasury portfolio purchase price and the aggregate separate NEE Capital debentures purchase price. The remarketing agents will then remit the separate NEE Capital debentures purchase price to the holders of NEE Capital debentures that were not a component of Corporate Units and whose holders elected to include those NEE Capital debentures in an early remarketing. The remarketing agents will then remit the remaining portion of the proceeds from the remarketing of those NEE Capital debentures, if any, for the benefit of the holders of the Corporate Units and the holders, prior to remarketing, of NEE Capital debentures that were not a component of Corporate Units and whose holders elected to include those NEE Capital debentures in an early remarketing.

As used in this context, “remarketing Treasury portfolio purchase price” means the lowest aggregate price quoted by a primary U.S. government securities dealer in New York City to the quotation agent on the applicable remarketing day during the period for early remarketing for the purchase of the remarketing Treasury portfolio described above for settlement on the reset effective date; provided that if the remarketing Treasury portfolio consists of cash, “remarketing Treasury portfolio purchase price” means an amount of cash equal to the aggregate principal amount at maturity of the U.S. Treasury securities (or principal or interest strips thereof) that would have otherwise been components of the remarketing Treasury portfolio. “Quotation agent” means any primary U.S. government securities dealer in New York City selected by NEE Capital.

Following a successful remarketing, interest on the NEE Capital debentures will be payable semi-annually at the reset rate. The reset rate on the NEE Capital debentures to the maturity date will be determined on the date that the remarketing agents are able to successfully remarket the NEE Capital debentures. The reset rate and the semi-annual interest payment dates will become effective, if the remarketing is successful, on the reset effective date, which, in the case of a remarketing during the period for early remarketing, will be the third business day immediately following the date of the successful remarketing, unless the remarketing is successful within five business days of the next succeeding interest payment date in which case the reset effective date will be such interest payment date. See “—General,” “—Interest and Payment” and “—Market Reset Rate” under “Description of the NEE Capital Debentures.” The interest rate and scheduled interest payment dates of NEE Capital debentures that are held by holders that do not participate in a remarketing will still be reset on the reset effective date in accordance with any reset of the interest rate and modification of the scheduled interest payment dates of the NEE Capital debentures in connection with a successful remarketing.

If a remarketing attempt described above is unsuccessful on the first remarketing day of a three-day remarketing period, subsequent remarketings will be attempted as described above on each of the two following remarketing days in that three-day remarketing period until a successful remarketing occurs. If (1) despite using its commercially reasonable efforts, the remarketing agents cannot remarket the NEE Capital debentures at a price equal to at least 100% of the remarketing Treasury portfolio purchase price plus the separate NEE Capital debentures purchase price or (2) the remarketing has not occurred because a condition precedent to the remarketing has not been fulfilled, in each case resulting in an unsuccessful remarketing on each of the three remarketing days comprising the three-day remarketing period, the NEE Capital debentures will continue to be a component of the Corporate Units and additional remarketings may, subject to the next paragraph, be attempted during one or more subsequent three-day remarketing periods as described above.

Unless the NEE Capital debentures have been successfully remarketed on or prior to the ninth business day immediately preceding the Purchase Contract Settlement Date, the NEE Capital debentures that are components of the Corporate Units whose holders have failed to notify the purchase contract agent on or prior to the seventh business day preceding the Purchase Contract Settlement Date of their intention to settle the related purchase contracts with separate cash will, unless a special event redemption or mandatory redemption has occurred or will occur prior to the Purchase Contract Settlement Date, be remarketed during a three-day remarketing period beginning on and including the fifth business day, and ending on and including the third business day, immediately preceding the Purchase Contract Settlement Date. This three-day remarketing period is referred to as the “final three-day remarketing period,” and the third business day immediately preceding the Purchase Contract Settlement Date is referred to as the “final remarketing date.” The reset effective date relating to any remarketing during the final three-day remarketing period will be the Purchase Contract Settlement Date. In this remarketing, the

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remarketing agents will use their commercially reasonable efforts to obtain a price for the NEE Capital debentures equal to or greater than 100% of the aggregate principal amount of the NEE Capital debentures being remarketed plus the remarketing fee. In no event shall the price for the NEE Capital debentures being remarketed in this remarketing be less than the aggregate principal amount of the NEE Capital debentures being remarketed. A portion of the proceeds from this remarketing equal to the aggregate principal amount of the NEE Capital debentures that are components of the Corporate Units will be automatically applied to satisfy in full the Corporate Unit holders’ obligations to purchase NEE common stock on the Purchase Contract Settlement Date.

If a remarketing during the final three-day remarketing period is successful, the remarketing agents may deduct the remarketing fee from any portion of the proceeds from the remarketing of the NEE Capital debentures that is in excess of the aggregate principal amount of the remarketed NEE Capital debentures, which remarketing fee shall be 25 basis points (0.25%) of the aggregate principal amount of the NEE Capital debentures remarketed. The remarketing agents will then remit any remaining portion of the proceeds for the benefit of the holders. Corporate Unit holders whose component NEE Capital debentures are remarketed as well as holders of separate NEE Capital debentures who elect to participate in the remarketing will not otherwise be responsible for the payment of any remarketing fee in connection with any remarketing.

If the remarketing of the NEE Capital debentures on or prior to the final remarketing date is not successful because the remarketing agents cannot obtain a price of at least 100% of the aggregate principal amount of the NEE Capital debentures being remarketed or a condition precedent to such remarketing has not been fulfilled, all holders of NEE Capital debentures (including beneficial owners of NEE Capital debentures that are components of the Corporate Units) will have the right to put their NEE Capital debentures to NEE Capital on the Purchase Contract Settlement Date for an amount equal to the put price. A holder of Corporate Units will be deemed to have automatically exercised this put right with respect to the NEE Capital debentures that are components of such Corporate Units unless such holder has elected to settle the related purchase contracts with separate cash as described below under “—Notice to Settle with Cash.” Unless a holder of Corporate Units has so elected to settle the related purchase contracts with separate cash, such holder will be deemed to have elected to apply a portion of the put price equal to the principal amount of the NEE Capital debentures against such holder’s obligations to purchase NEE common stock under the related purchase contracts, thereby satisfying such obligations in full, and NEE will deliver to such holder NEE common stock pursuant to the related purchase contracts. Any amount of the put price remaining following settlement of such purchase contracts will be delivered to the purchase contract agent for the benefit of the holder of such Corporate Units.

NEE Capital will announce any remarketing of the NEE Capital debentures on the sixth business day immediately preceding the first remarketing day of a three-day remarketing period and, for the final three-day remarketing period, NEE Capital will announce the remarketing of the NEE Capital debentures on the third business day immediately preceding the first remarketing day of the final three-day remarketing period. Each such announcement (each a “remarketing announcement”) on each such date (each, a “remarketing announcement date”) shall specify

•if the remarketing announcement relates to a remarketing to occur during the period for early remarketing, that

•the NEE Capital debentures may be remarketed on any and all of the sixth, seventh or eighth business days following the remarketing announcement date,

•the reset effective date will be the third business day following the remarketing date on which the NEE Capital debentures are successfully remarketed, unless the remarketing is successful within five business days of the next succeeding interest payment date in which case the reset effective date will be such interest payment date,

•the reset rate and interest payment dates for the NEE Capital debentures will be established on the remarketing date on which the NEE Capital debentures are successfully remarketed and effective on and after the reset effective date,

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•the reset rate will equal the coupon rate on the NEE Capital debentures that will enable the NEE Capital debentures to be remarketed at a price equal to 100% of the remarketing Treasury portfolio purchase price and the aggregate separate NEE Capital debentures purchase price plus the remarketing fee, and

•the remarketing fee will equal 25 basis points (0.25%) of the sum of the remarketing Treasury portfolio purchase price and the aggregate separate NEE Capital debentures purchase price.

•if the remarketing announcement relates to a remarketing to occur during the final three-day remarketing period, that

•the NEE Capital debentures may be remarketed on any and all of the third, fourth or fifth business days following the remarketing announcement date,

•the reset effective date will be the Purchase Contract Settlement Date if there is a successful remarketing,

•the reset rate and interest payment dates for the NEE Capital debentures will be established on the remarketing date on which the NEE Capital debentures are successfully remarketed and effective on and after the reset effective date,

•the reset rate will equal the coupon rate on the NEE Capital debentures that will enable the NEE Capital debentures to be remarketed at a price equal to 100% of their aggregate principal amount plus the remarketing fee, and

•the remarketing fee will equal 25 basis points (0.25%) of the aggregate principal amount of the NEE Capital debentures being remarketed.

NEE Capital will cause each remarketing announcement to be published on or prior to the business day following the remarketing announcement date by making a timely release to any appropriate news agency, including Bloomberg News and the Dow Jones Newswires. In addition, NEE Capital will request, not later than ten business days prior to each remarketing announcement date, that the Depositary notify its participants holding NEE Capital debentures, Corporate Units and Treasury Units of the remarketing. If required, NEE Capital will use its commercially reasonable efforts to ensure that a registration statement with respect to the full principal amount of the NEE Capital debentures to be remarketed is effective such that the remarketing agents may rely on it in connection with the remarketing process. If a successful remarketing occurs on a remarketing date, NEE Capital will request the Depositary to notify its participants holding separate NEE Capital debentures of the reset rate and interest payment dates established for the NEE Capital debentures during the remarketing on the business day following the remarketing date on which the NEE Capital debentures were successfully remarketed. If a successful remarketing does not occur during a three-day remarketing period, NEE Capital will cause a notice of the unsuccessful remarketing attempt to be published on the business day following the last of the three remarketing days comprising the three-day remarketing period (which notice, in the event of an unsuccessful remarketing on the final remarketing date, shall be published not later than 9:00 a.m., New York City time, and shall include the procedures that must be followed if a holder of separate NEE Capital debentures wishes to exercise its right to put such NEE Capital debentures to NEE Capital), in each case, by making a timely release to any appropriate news agency, including Bloomberg News and the Dow Jones Newswires.

In connection with a remarketing, holders of NEE Capital debentures that are not a component of the Corporate Units may elect to have their NEE Capital debentures remarketed as described under “Description of the NEE Capital Debentures—Optional Remarketing.”

A holder of Corporate Units may elect not to participate in any remarketing and to retain its applicable ownership interests in NEE Capital debentures that are components of the holder’s Corporate Units by (1) creating Treasury Units at any time prior to the business day preceding any three-day remarketing period, (2) if there has not been a successful remarketing prior to the final three-day remarketing period, providing written notice to the

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purchase contract agent of the holder’s intention to pay cash to satisfy its obligation under the related purchase contracts on or prior to the seventh business day before the Purchase Contract Settlement Date and delivering the cash payment required under the purchase contracts to the collateral agent on or prior to the sixth business day before the Purchase Contract Settlement Date or (3) settling the related purchase contracts early.

Early Settlement by Delivering Cash

At any time prior to the seventh business day immediately preceding the Purchase Contract Settlement Date, in the case of Corporate Units (of which the applicable ownership interest in a NEE Capital debenture remains a component), or at any time prior to the second business day immediately preceding the Purchase Contract Settlement Date, in the case of Treasury Units (or Corporate Units of which the applicable ownership interest in a NEE Capital debenture no longer is a component, or which remains a component because a successful remarketing did not occur during the final three-day remarketing period), a holder of Equity Units may settle the related purchase contracts in their entirety provided that at such time, if so required under the U.S. federal securities laws, there is in effect a registration statement covering the shares of common stock to be delivered in respect of the purchase contracts being settled, by presenting and surrendering the related Equity Units certificate at the office of the purchase contract agent with the form of “Election to Settle Early/Fundamental Change Early Settlement” on the reverse side of such certificate completed and executed as indicated, accompanied by payment to NEE in immediately available funds of an amount equal to:

•$50 multiplied by the number of purchase contracts being settled, plus

•if the delivery is made with respect to any purchase contract during the period from the close of business on any record date next preceding any payment date to the opening of business on such payment date, an amount equal to the contract adjustment payments payable, if any, on the payment date with respect to the purchase contract; provided that no payment is required if NEE has elected to defer the contract adjustment payments which would otherwise be payable on the payment date.

If a purchase contract is settled early other than on a fundamental change early settlement date, and other than as discussed under “—Option to Defer Contract Adjustment Payments” with respect to deferred contract adjustment payments, a holder will have no right to receive any accrued and unpaid contract adjustment payments.

If the Treasury portfolio has not replaced the NEE Capital debentures as a component of Corporate Units, holders of Corporate Units will not be permitted to exercise their early settlement right during any period commencing on and including the business day preceding any three-day remarketing period and ending on and including, in the case of a successful remarketing during that three-day remarketing period, the reset effective date or, if none of the remarketings during that three-day remarketing period is successful, the business day following the last remarketing date in the applicable three-day remarketing period.

Holders of Corporate Units may settle early only in integral multiples of 20 Corporate Units. If a Treasury portfolio has replaced the NEE Capital debentures as a component of Corporate Units as a result of a successful remarketing of the NEE Capital debentures, a special event redemption or a mandatory redemption, holders of Corporate Units may settle early only in integral multiples of the Minimum Number of Corporate Units (or such other number of Corporate Units as may be determined by the remarketing agents upon a successful remarketing of NEE Capital debentures if the reset effective date is not a regular quarterly interest payment date). Holders of Treasury Units may settle early only in integral multiples of 20 Treasury Units.

So long as the Equity Units are evidenced by one or more global security certificates deposited with the Depositary, procedures for early settlement will also be governed by standing arrangements between the Depositary and the purchase contract agent.

The early settlement right is also subject to the condition that, if so required under the U.S. federal securities laws, NEE has a registration statement under the Securities Act of 1933 in effect covering the shares of NEE common stock and other securities, if any, deliverable upon settlement of a purchase contract. NEE has agreed that, if so required under the U.S. federal securities laws, NEE will use its commercially reasonable efforts to

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(1) have a registration statement in effect covering those shares of common stock and other securities to be delivered in respect of the purchase contracts being settled, and (2) provide a prospectus in connection therewith, in each case in a form that may be used in connection with the early settlement.

Upon early settlement of the purchase contracts related to any Corporate Units or Treasury Units:

•the holder will receive a number of newly issued shares of NEE common stock equal to the Minimum Settlement Rate per Corporate Unit or Treasury Unit, regardless of the market price of NEE common stock on the date of early settlement, subject to adjustment under the circumstances described under “—Anti-dilution Adjustments” below, accompanied by an appropriate prospectus if required by law;

•the NEE Capital debentures, the applicable ownership interest in the Treasury portfolio or the Treasury securities, as the case may be, related to the Corporate Units or Treasury Units will be transferred to the holder free and clear of NEE’s security interest;

•the holder’s right to receive future contract adjustment payments will terminate and any accrued and unpaid contract adjustment payments for the period since the most recent quarterly payment date will terminate; and

•no adjustment will be made to or for the holder on account of any accrued and unpaid contract adjustment payments referred to in the previous bullet point.

NEE will not issue any fractional shares of its common stock in connection with early settlement of any purchase contracts. In lieu of fractional shares otherwise issuable (calculated on an aggregate basis) in respect of the purchase contracts being early settled on any date by a holder of Corporate Units or Treasury Units, the holder will be entitled to receive an amount of cash equal to the fraction of a share multiplied by the Threshold Appreciation Price.

If the purchase contract agent receives an Equity Unit certificate, accompanied by the completed and executed “Election to Settle Early/Fundamental Change Early Settlement” and the required immediately available funds, from a holder of Equity Units by 5:00 p.m., New York City time, on a business day, that day will be considered the settlement date for the purchase contracts that form a component of those Equity Units. If the purchase contract agent receives the necessary documentation and funds after 5:00 p.m., New York City time, on a business day or at any time on a day that is not a business day, the next business day will be considered the settlement date for the purchase contracts that form a component of those Equity Units.

Upon early settlement of purchase contracts in the manner described above, presentation and surrender of the Equity Unit certificate evidencing the related Corporate Units or Treasury Units and payment of any transfer or similar taxes payable by the holder in connection with the issuance of the related NEE common stock to any person other than the holder of the Corporate Units or Treasury Units, NEE will cause the shares of its common stock being purchased to be issued, and the related NEE Capital debentures, the applicable ownership interest in the Treasury portfolio or the Treasury securities, as the case may be, securing the purchase contracts to be released from the pledge under the pledge agreements described under “—Pledged Securities and Pledge Agreements” and transferred, within three business days following the settlement date, to the purchasing holder or the holder’s designee.

Early Settlement upon a Fundamental Change

Prior to the Purchase Contract Settlement Date, if NEE is involved in a transaction that constitutes a fundamental change (as defined below), then following the fundamental change each holder of an Equity Unit will have the right to accelerate and settle the related purchase contract that is a component of the Equity Unit early at the settlement rate determined as if the applicable market value equaled the stock price (as defined below), plus an additional make-whole amount of shares (such additional make-whole amount of shares being hereafter referred to as the “make-whole shares”), provided that at such time, if so required under the U.S. federal securities laws, there is

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in effect a registration statement covering the common stock and other securities, if any, to be delivered in respect of the purchase contracts being settled. This right is referred to as the “fundamental change early settlement right.”

NEE will provide each holder of an Equity Unit with a notice of the completion of a fundamental change within five business days thereof. The notice will specify a date, which shall be at least ten days after the date of the notice but no later than the earlier of 20 days after the date of such notice or five business days prior to the Purchase Contract Settlement Date, by which each holder’s fundamental change early settlement right must be exercised. The notice will set forth, among other things, the applicable settlement rate and the kind and amount of securities, cash or other consideration receivable by the holder upon settlement. To exercise the fundamental change early settlement right, a holder of an Equity Unit must deliver to the purchase contract agent, no later than 4:00 p.m., New York City time, on the third business day before the fundamental change early settlement date, the certificate or certificates evidencing its Corporate Units or Treasury Units, and payment of the applicable purchase price in immediately available funds.

A “fundamental change” will be deemed to have occurred if either of the following occurs:

(1)a “person” or “group” within the meaning of Section 13(d) of the Securities Exchange Act of 1934 has become the direct or indirect “beneficial owner,” as defined in Rule 13d-3 under the Securities Exchange Act of 1934, of NEE common stock representing more than 50% of the voting power of NEE common stock; or

(2)NEE is involved in a consolidation with or merger into any other person, or any merger of another person into NEE, or any transaction or series of related transactions (other than a merger or consolidation that does not result in any reclassification, conversion, exchange or cancellation of outstanding shares of NEE common stock), in each case in which 10% or more of the total consideration paid to NEE’s shareholders consists of cash or cash equivalents.

If a holder exercises the fundamental change early settlement right, NEE will deliver to the holder on the fundamental change early settlement date the kind and amount of securities, cash or other consideration that the holder would have been entitled to receive if it had settled the purchase contract immediately before the fundamental change at the settlement rate described above, plus the additional make-whole shares. The holder will also receive the NEE Capital debentures, the applicable ownership interest in the Treasury portfolio or the Treasury securities that are a component of the Corporate Units or Treasury Units, as the case may be. If a holder of an Equity Unit does not elect to exercise its fundamental change early settlement right, its Corporate Units or Treasury Units will remain outstanding and subject to normal settlement on the Purchase Contract Settlement Date. NEE has agreed that, if so required under the U.S. federal securities laws, NEE will use its commercially reasonable efforts to (1) have in effect a registration statement covering the securities, if any, to be delivered in respect of the purchase contracts being settled and (2) provide a prospectus in connection therewith, in each case in a form that may be used in connection with an early settlement upon a fundamental change. In the event that a holder seeks to exercise its fundamental change early settlement right and a registration statement is required to be effective in connection with the exercise of such right but no such registration statement is then effective, the holder’s exercise of such right shall be void unless and until such a registration statement shall be effective and NEE will have no further obligation with respect to any such registration statement if, notwithstanding using its commercially reasonable efforts, no registration statement is then effective.

If the Treasury portfolio has replaced the NEE Capital debentures as a component of the Corporate Units, holders of Corporate Units may exercise the fundamental change early settlement right only in integral multiples of the Minimum Number of Corporate Units (or such other number of Corporate Units as may be determined by the remarketing agents upon a successful remarketing of the NEE Capital debentures if the reset effective date is not a regular quarterly interest payment date). Otherwise, a holder of Corporate Units or Treasury Units may exercise the fundamental change early settlement right only in integral multiples of 20 Corporate Units or 20 Treasury Units, respectively.

Calculation of the Number of Make-Whole Shares. The number of make-whole shares per purchase contract applicable to a fundamental change early settlement will be determined by reference to the applicable

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Fundamental Change Early Settlement Table (set forth in Annex A), based on the date on which the fundamental change becomes effective (the “effective date”) and the “stock price” in the fundamental change, which will be:

•in the case of a fundamental change described in clause (2) in the definition of “fundamental change” above and the holders of NEE common stock receive only cash in such fundamental change, the stock price paid per share will be the cash amount paid per share; or

•otherwise, the stock price paid per share will be the average of the closing prices of NEE common stock over the 20 consecutive trading day period ending on the trading day immediately preceding the effective date of the fundamental change.

The stock prices set forth in the first column heading of the Fundamental Change Early Settlement Tables will be adjusted upon the occurrence of certain events requiring anti-dilution adjustments to the fixed settlement rates. Each of the make-whole share amounts in the tables will be subject to adjustment in the same manner as the fixed settlement rates. See “—Anti-dilution Adjustments.”

The exact stock price and effective date applicable to a fundamental change may not be set forth on the table, in which case:

•if the stock price is between two stock price amounts on the table or the effective date is between two dates on the table, the amount of make-whole shares will be determined by straight line interpolation between the make-whole share amounts set forth for the higher and lower stock price amounts and the two dates, as applicable, based on a 365-day year;

•if the stock price is in excess of the Fundamental Change Early Settlement Table High Price (as defined in Annex A) per share (subject to adjustment as described above), then the amount of make-whole shares will be zero; and

•if the stock price is less than the Fundamental Change Early Settlement Table Low Price (as defined in Annex A) per share (subject to adjustment as described above) (the “minimum stock price”), then the amount of make-whole shares will be determined as if the stock price equaled the minimum stock price, using straight line interpolation, as described above, if the effective date is between two dates on the table.

Notice to Settle with Cash

A holder of a Corporate Unit (of which the applicable ownership interest in a NEE Capital debenture remains a component) that wishes to settle the related purchase contract with separate cash prior to the final three-day remarketing period must notify the purchase contract agent by presenting and surrendering the certificate evidencing the Corporate Unit at the office of the purchase contract agent with the form of “Notice to Settle by Separate Cash” on the reverse side of the certificate completed and executed as indicated on or prior to 5:00 p.m., New York City time, on the seventh business day immediately preceding the Purchase Contract Settlement Date and delivering the required cash payment to the collateral agent on or prior to 11:00 a.m., New York City time, on the sixth business day immediately preceding the Purchase Contract Settlement Date.

A holder of a Treasury Unit or a Corporate Unit (of which the applicable ownership interest in a NEE Capital debenture is no longer a component or remains a component because a successful remarketing did not occur during the final three-day remarketing period) that wishes to settle the related purchase contract with separate cash must notify the purchase contract agent by presenting and surrendering the certificate representing the Treasury Unit or the certificate evidencing the Corporate Unit, as the case may be, at the office of the purchase contract agent with the form of “Notice to Settle by Separate Cash” on the reverse side of such certificate completed and executed as indicated on or prior to 5:00 p.m., New York City time, on the second business day immediately preceding the Purchase Contract Settlement Date and delivering the required cash payment to the collateral agent on or prior to 11:00 a.m., New York City time, on the business day immediately preceding the Purchase Contract Settlement Date.

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Upon cash settlement, the NEE Capital debenture or the applicable ownership interest in a Treasury portfolio, as the case may be, related to the Corporate Units will be transferred to the holder free and clear of NEE’s security interest. The holder of the Corporate Units will then receive the applicable number of shares of NEE common stock on the Purchase Contract Settlement Date.

Upon cash settlement, the Treasury security related to the Treasury Units will be transferred to the holder free and clear of NEE’s security interest. The holder of the Treasury Units will then receive the applicable number of shares of NEE common stock on the Purchase Contract Settlement Date.

If a holder of a Corporate Unit that has given notice of its intention to settle the purchase contract with separate cash fails to deliver the cash to the collateral agent by the applicable time and date specified above, the NEE Capital debentures component of such holder’s Corporate Units will automatically be remarketed, or if the NEE Capital debentures are not successfully remarketed during the final three-day remarketing period, all holders of NEE Capital debentures (including beneficial owners of NEE Capital debentures that are components of the Corporate Units) will have the right to put their NEE Capital debentures to NEE Capital as described under
“—Remarketing” above.

If a holder of a Treasury Unit that has given notice of its intention to settle the purchase contract with separate cash fails to deliver the cash to the collateral agent by the applicable time and date specified above, the proceeds of the Treasury security component of such holder’s Treasury Unit will be used to satisfy the holder’s obligation to purchase NEE common stock under the related purchase contract.

Contract Adjustment Payments

Contract adjustment payments in respect of Corporate Units and the Treasury Units are fixed at the Contract Adjustment Rate on $50 per purchase contract per year. Contract adjustment payments payable for any period will be computed on the basis of a 360-day year consisting of twelve 30-day months. The amount of contract adjustment payments for any period shorter than a full quarterly period for which contract adjustments payments are computed will be computed on the basis of the number of days in the period using 30-day calendar months. Contract adjustment payments will accrue from the Closing Date (as defined in Annex A) and will be payable quarterly in arrears on March 1, June 1, September 1 and December 1 of each year, commencing the Initial Payment Date (as defined in Annex A).

Contract adjustment payments will be payable to the holders of purchase contracts as they appear on the books and records of the purchase contract agent on the relevant record dates, which, as long as all of the Equity Units remain in book-entry only form, will be the close of business on the business day immediately prior to the relevant payment date. These distributions will be paid through the purchase contract agent, who will hold amounts received in respect of the contract adjustment payments for the benefit of the holders of the purchase contracts relating to the Equity Units. Subject to any applicable laws and regulations, each such payment will be made as described under “—Book-Entry Only System.” In the event that all of the Equity Units do not remain in book-entry only form, NEE shall have the right to select relevant record dates, which shall be at least one business day but not more than 60 business days prior to the relevant payment dates, and to make payments by check mailed to the specified address of the holder as of the relevant record date or by wire transfer to an account appropriately designated by the holder entitled to payment.

If any date on which contract adjustment payments are to be made is not a business day, then payment of the contract adjustment payments payable on that date will be made on the next succeeding day which is a business day, and no interest or payment will be paid in respect of the delay. However, if such next succeeding business day is in the next succeeding calendar year, that payment will be made on the business day immediately preceding the scheduled payment date, in each case with the same force and effect as if made on that scheduled payment date. A “business day” means any day other than a Saturday, Sunday or any other day on which banking institutions and trust companies in New York City are permitted or required by any applicable law, regulation or executive order to close.

NEE’s obligations with respect to contract adjustment payments will be subordinate and junior in right of payment to its obligations under any of its senior indebtedness. Upon any payment or distribution of assets of NEE

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to its creditors upon any dissolution, winding up, liquidation or reorganization, whether voluntary or involuntary, or in bankruptcy, insolvency, receivership or other similar proceedings, the holders of NEE’s senior indebtedness shall first be entitled to receive payment in full of all amounts due or to become due thereon, or payment of such amounts shall have been provided for, before the holders of Equity Units shall be entitled to receive any contract adjustment payments with respect to any Equity Unit.

By reason of this subordination, in those events, holders of NEE’s senior indebtedness may receive more, ratably, and holders of the Equity Units may receive less, ratably, than NEE’s other creditors. Because NEE is a holding company, contract adjustment payments on the Equity Units are effectively subordinated to all indebtedness and other liabilities, including trade payables, debt and preferred stock issued, guaranteed or otherwise incurred by NEE’s subsidiaries. NEE’s subsidiaries are separate and distinct legal entities and have no obligation to pay any contract adjustment payments or to make any funds available for such payment.

In addition, no payment of contract adjustment payments with respect to any Equity Units may be made if:

•any payment default on any senior indebtedness of NEE has occurred and is continuing beyond any applicable grace period; or

•any default on any indebtedness of NEE (other than a payment default with respect to senior indebtedness) occurs and is continuing that permits the acceleration of the maturity on any indebtedness of NEE and the purchase contract agent receives a written notice of such default from NEE or the holders of such senior indebtedness.

Option to Defer Contract Adjustment Payments

NEE may, at its option and upon prior written notice to the holders of the Equity Units and the purchase contract agent, defer the payment of contract adjustment payments on the related purchase contracts that are a component of the Equity Units otherwise payable on a payment date to any subsequent payment date (a “deferral period”) until no later than the Purchase Contract Settlement Date; provided, however, that in an early settlement upon a fundamental change or any other early settlement of the purchase contracts, NEE will pay deferred contract adjustment payments to but not including the fundamental change settlement date or the most recent quarterly payment date, as applicable. Prior to the expiration of any deferral period, NEE may further extend such deferral period to any subsequent payment date, but not beyond the Purchase Contract Settlement Date (or any applicable early settlement date or fundamental change early settlement date). Any deferred contract adjustment payments will accrue additional contract adjustment payments at the Corporate Unit Aggregate Rate per year until paid, compounded quarterly, which is equal to the rate of total distributions on the Corporate Units. If a purchase contract is settled early other than on a fundamental change early settlement date, and other than as discussed above with respect to deferred contract adjustment payments, a holder will have no right to receive any accrued and unpaid contract adjustment payments. In addition, if the purchase contracts are terminated upon the occurrence of certain events of bankruptcy, insolvency or reorganization with respect to NEE, the right to receive any accrued and unpaid contract adjustment payments and deferred contract adjustment payments will also terminate.

In the event that NEE exercises its right to defer the payment of contract adjustment payments, then, until the deferred contract adjustment payments have been paid, NEE will not declare or pay dividends on, make other distributions with respect to, or redeem, purchase or acquire, or make a liquidation payment with respect to, any of its capital stock or make guarantee payments with respect to the foregoing other than:

•purchases, redemptions or other acquisitions of NEE Capital stock in connection with any employment contract, benefit plan or other similar arrangement with or for the benefit of any one or more employees, officers, directors, consultants or agents or a stock purchase or dividend reinvestment plan, or the satisfaction of its obligations pursuant to any contract or security, outstanding on the date that the payment of contract adjustment payments is deferred requiring NEE to purchase, redeem or acquire its capital stock;

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•as a result of a reclassification of NEE’s Capital stock or the exchange or conversion of all or a portion of one class or series of its capital stock, or the capital stock of one of its subsidiaries, for another class or series of its capital stock;

•any exchange, redemption or conversion of any class or series of its indebtedness for any class or series of its capital stock;

•the purchase of fractional interests in shares of NEE Capital stock pursuant to the conversion or exchange provisions of the capital stock or the security being converted or exchanged, or in connection with the settlement of stock purchase contracts;

•dividends or other distributions paid or made in NEE Capital stock (or rights to acquire NEE Capital stock), or repurchases, redemptions or acquisitions of capital stock in connection with the issuance or exchange of capital stock (or of securities convertible into or exchangeable for shares of NEE Capital stock) and distributions in connection with the settlement of stock purchase contracts); or

•redemptions, exchanges or repurchases of, or with respect to, any rights outstanding under a shareholder rights plan or the declaration or payment thereunder of a dividend or other distribution of or with respect to rights in the future.

NEE’s subsidiaries will not be restricted from making any similar payments on their capital stock if NEE exercises its right to defer payment of any contract adjustment payments.

Anti-dilution Adjustments

In order to maintain a holder’s relative investment in NEE common stock upon the occurrence of certain events, each fixed settlement rate will be subject to the following adjustments:

(1) Stock Dividends. If NEE pays or makes a dividend or other distribution on NEE common stock in such common stock, each fixed settlement rate in effect at the opening of business on the day following the date fixed for the determination of shareholders entitled to receive such dividend or other distribution shall be increased by dividing:

•such fixed settlement rate by

•a fraction, the numerator of which shall be the number of shares of NEE common stock outstanding at the close of business on the date fixed for such determination and the denominator of which shall be the sum of such number of shares and the total number of shares constituting such dividend or other distribution.

(2) Stock Purchase Rights. If NEE issues to all holders of NEE common stock, rights, options, warrants or other securities (that are not available on an equivalent basis to holders of the Equity Units upon settlement of the purchase contracts), entitling them to subscribe for or purchase shares of NEE common stock for a period expiring within 45 days from the date of issuance of such rights, options, warrants or other securities at a price per share of NEE common stock less than the current market price (as defined below) on the date fixed for the determination of shareholders entitled to receive such rights, options, warrants or other securities (other than pursuant to a dividend reinvestment, stock purchase or similar plan), each fixed settlement rate in effect at the opening of business on the day following the date fixed for such determination shall be increased by dividing:

•such fixed settlement rate by

•a fraction, the numerator of which shall be the number of shares of NEE common stock outstanding at the close of business on the date fixed for such determination plus the number of shares of NEE common stock which the aggregate consideration expected to be received by NEE upon the exercise, conversion or exchange of such rights, options, warrants or other securities would purchase at such

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current market price and the denominator of which shall be the number of shares of NEE common stock outstanding at the close of business on the date fixed for such determination plus the number of shares of NEE common stock so offered for subscription or purchase, either directly or indirectly.

(3) Stock Splits, Reverse Splits and Combinations. If outstanding shares of NEE common stock shall be subdivided, split or reclassified into a greater number of shares of NEE common stock, each fixed settlement rate in effect at the opening of business on the day following the day upon which such subdivision, split or reclassification becomes effective shall be proportionately increased, and, conversely, in case outstanding shares of NEE common stock shall each be combined or reclassified into a smaller number of shares of NEE common stock, each fixed settlement rate in effect at the opening of business on the day following the day upon which such combination or reclassification becomes effective shall be proportionately reduced.

(4) Debt or Asset Distributions. If NEE, by dividend or otherwise, distributes to all holders of NEE common stock evidences of its indebtedness or assets (including securities but excluding any rights, options, warrants or other securities referred to in paragraph (2) above, any dividend or other distribution paid exclusively in cash referred to in paragraph (5) below (including the Reference Dividend (as defined in Annex A), as described therein) and any dividend or other distribution of shares of capital stock of any class or series, or similar equity interests, of or relating to a subsidiary or other business unit in the case of a spin-off referred to below, or dividend or other distribution referred to in paragraph (1) above), each fixed settlement rate in effect immediately prior to the close of business on the date fixed for the determination of shareholders entitled to receive such distribution shall be increased by dividing:

•such fixed settlement rate by

•a fraction, the numerator of which shall be the current market price on the date fixed for such determination less the then fair market value (as determined in good faith by NEE’s board of directors, whose good faith determination will be conclusive) of the portion of the assets or evidences of indebtedness so distributed applicable to one share of NEE common stock and the denominator of which shall be such current market price.

In the case of the payment of a dividend or other distribution on NEE common stock of shares of capital stock of any class or series, or similar equity interests, of or relating to a subsidiary or other business unit of NEE, which is referred to as a “spin-off,” the fixed settlement rates in effect immediately before the close of business on the record date fixed for determination of shareholders entitled to receive that distribution will be increased by dividing:

•such fixed settlement rate by

•a fraction, the numerator of which shall be the current market price of NEE common stock and the denominator of which shall be such current market price plus the fair market value (as determined in good faith by NEE’s board of directors, whose good faith determination will be conclusive) of those shares of capital stock or similar equity interests so distributed applicable to one share of common stock.

The adjustment to the fixed settlement rates under the preceding paragraph will occur on the date that is the earlier of:

•the tenth trading day from and including the effective date of the spin-off; and

•in the case of any spin-off that is effected simultaneously with an initial public offering of the securities being distributed in the spin-off, the date on which the initial public offering price of the securities being offered in such initial public offering is determined.

For purposes of this section, “initial public offering” means the first time securities of the same class or type as the securities being distributed in the spin-off are offered to the public for cash.

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In the event of a spin-off that is not effected simultaneously with an initial public offering of the securities being distributed in the spin-off, the fair market value of the securities to be distributed to holders of NEE common stock means the average of the closing sale prices of those securities over the first ten trading days following the effective date of the spin-off. Also, for purposes of such a spin-off, the current market price of NEE common stock means the average of the closing sale prices of NEE common stock over the first ten trading days following the effective date of the spin-off.

If, however, an initial public offering of the securities being distributed in the spin-off is to be effected simultaneously with the spin-off, the fair market value of the securities being distributed in the spin-off means the initial public offering price, while the current market price of NEE common stock means the closing sale price of NEE common stock on the trading day on which the initial public offering price of the securities being distributed in the spin-off is determined.

(5) Cash Distributions. If NEE, by dividend or otherwise, makes distributions to all holders of NEE common stock exclusively in cash during any fiscal quarter (excluding any cash that is distributed in a reorganization event to which the provisions described below under “—Reorganization Events” apply or as part of a distribution referred to in paragraph (4) above) in an amount that exceeds the Reference Dividend per share of NEE common stock, immediately after the close of business on the date fixed for determination of the shareholders entitled to receive such distribution, each fixed settlement rate shall be increased by dividing:

•each fixed settlement rate by

•a fraction, the numerator of which shall be equal to the current market price on the date fixed for such determination less the per share amount of the distribution and the denominator of which shall be equal to such current market price minus the Reference Dividend.

The Reference Dividend is subject to adjustment (without duplication) from time to time whenever the fixed settlement rates are adjusted, in a manner inversely proportional to any such adjustment, provided that no adjustment will be made to the Reference Dividend for any adjustment made to the fixed settlement rates pursuant to this paragraph (5). In the event that such dividend or other distribution is not so paid or made, each fixed settlement rate shall again be adjusted to be the fixed settlement rates which would then be in effect if such dividend or other distribution had not been declared.

(6) Tender and Exchange Offers. In case a tender offer or exchange offer made by NEE or any subsidiary for all or any portion of NEE common stock shall expire and such tender offer or exchange offer (as amended through the expiration thereof) shall require the payment to shareholders (based on the acceptance (up to any maximum specified in the terms of the tender offer or exchange offer) of reacquired shares (as defined below)) of an aggregate consideration having a fair market value per share (as determined in good faith by NEE’s board of directors, whose good faith determination will be conclusive) of NEE common stock that exceeds the closing price of NEE common stock on the trading day next succeeding the last date on which tenders or exchanges may be made pursuant to such tender offer or exchange offer, then, immediately prior to the opening of business on the trading day after the date of the last time (which is referred to as the “expiration time”) tenders or exchanges could have been made pursuant to such tender offer or exchange offer (as amended through the expiration thereof), each fixed settlement rate shall be increased by dividing:

•each fixed settlement rate immediately prior to the close of business on the date of the expiration time by

•a fraction (A) the numerator of which shall be equal to (i) the product of (x) the current market price of NEE common stock on the date of the expiration time and (y) the number of shares of common stock outstanding (including any tendered or exchanged shares) on the date of the expiration time less (ii) the amount of cash plus the fair market value (as determined in good faith by NEE’s board of directors, whose good faith determination will be conclusive) of the aggregate consideration if any, other than cash, payable to shareholders pursuant to the tender offer or exchange offer (assuming the acceptance, up to any maximum specified in the terms of the tender offer or exchange offer, of reacquired shares),

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and (B) the denominator of which shall be equal to the product of (i) the current market price on the date of the expiration time and (ii) the result of (x) the number of shares of NEE common stock outstanding (including any tendered or exchanged shares) on the date of the expiration time less (y) the number of all shares validly tendered pursuant to the tender offer or exchange offer, not withdrawn and accepted on the date of the expiration time (such validly tendered or exchanged shares, up to any such maximum, being referred to as the “reacquired shares”).

The “current market price” per share of NEE common stock or any other security on any day means the average of the daily closing prices for the 20 consecutive trading days preceding the earlier of the day immediately preceding the day in question and the day before the “ex date” with respect to the issuance or distribution requiring such computation. For purposes of this paragraph, the term “ex date,” when used with respect to any issuance or distribution, means the first date on which NEE common stock or such other security, as applicable, trades, regular way, on the principal U.S. securities exchange or quotation system on which NEE common stock or such other security, as applicable, is listed or quoted at that time, without the right to receive the issuance or distribution.

Reorganization Events. The following events are defined as “reorganization events”:

•any consolidation or merger of NEE with or into another person or of another person with or into NEE, except in cases where NEE is the continuing entity and NEE common stock outstanding immediately prior to the consolidation or merger is not exchanged for cash, securities or other property of NEE or another person;

•any sale, transfer, lease or conveyance to another person of the property of NEE as an entirety or substantially as an entirety;

•any statutory share exchange business combination of NEE with another person (other than a statutory share exchange business combination in which NEE is the continuing entity and in which NEE common stock outstanding immediately prior to the statutory share exchange business combination is not exchanged for cash, securities or other property of NEE or another person); or

•any liquidation, dissolution or winding up of NEE (other than as a result of, or after the occurrence of, bankruptcy, insolvency or reorganization of NEE).

Upon a reorganization event, each Equity Unit shall thereafter, in lieu of a variable number of shares of NEE common stock, be settled by delivery of exchange property units. An “exchange property unit” represents the right to receive the kind and amount of securities, cash and other property receivable in such reorganization event (without any interest thereon, and without any right to dividends or other distributions thereon which have a record date that is prior to the applicable settlement date) per share of NEE common stock by a holder of common stock that is not a person with which NEE is consolidated or into which NEE is merged or which merged into NEE or to which such sale or transfer was made, as the case may be (any such person is referred to as a “constituent person”), or an affiliate of a constituent person, to the extent such reorganization event provides for different treatment of common stock held by NEE’s affiliates and non-affiliates. In the event that holders of NEE common stock have the opportunity to elect the form of consideration to be received in such transaction, the exchange property unit that holders of the Corporate Units or Treasury Units would have been entitled to receive will be deemed to be the weighted average of the types and amounts of consideration received by the holders of NEE common stock that affirmatively make an election.

In the event of such a reorganization event, the person formed by such consolidation or merger or the person which acquires NEE’s assets shall execute and deliver to the purchase contract agent an agreement providing that the holder of each Equity Unit that remains outstanding after the reorganization event (if any) shall have the rights described in the preceding paragraph. Such supplemental agreement shall provide for adjustments to the amount of any securities constituting all or a portion of an exchange property unit which, for events subsequent to the effective date of such reorganization event, shall be as nearly equivalent as may be practicable to the adjustments provided for in this “—Anti-dilution Adjustments” section. The provisions described in the preceding two paragraphs shall similarly apply to successive reorganization events.

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Holders have the right to settle their obligations under the Equity Units early in the event of certain fundamental changes as described above under “—Early Settlement upon a Fundamental Change.”

A holder of Equity Units may be treated as receiving a constructive distribution from NEE with respect to the purchase contract if (1) the fixed settlement rates are adjusted (or fail to be adjusted) and, as a result of the adjustment (or failure to adjust), the holder’s proportionate interest in NEE’s assets or earnings and profits is increased, and (2) the adjustment (or failure to adjust) is not made pursuant to a bona fide, reasonable anti-dilution formula. Thus, under certain circumstances, an increase in (or a failure to decrease) the fixed settlement rates might give rise to a taxable dividend to a holder of Equity Units even though such holder will not receive any cash in connection with the increase in (or failure to decrease) such fixed settlement rate. In addition, non-U.S. holders of Equity Units may, in certain circumstances, be deemed to have received a distribution subject to U.S. federal withholding tax. See “United States Federal Income Tax Discussion—U.S. Holders—Purchase Contracts—Adjustment to Settlement Rate” and “—Non-U.S. Holders—Dividends.”

In addition, NEE may, but shall not be required to, increase a fixed settlement rate if its board of directors considers it to be advisable to avoid or diminish any income tax to any holders of shares of its common stock resulting from any dividend or distribution of stock or issuance of rights or warrants to purchase or subscribe for stock or from any event treated as such for income tax purposes or for any other reason.

NEE currently does not have a shareholder rights plan with respect to NEE common stock. If NEE later adopts any shareholder rights plan involving the issuance of preferred share purchase rights or other similar rights (the “rights”) to all holders of its common stock, a holder of Equity Units shall be entitled to receive upon settlement of any purchase contract, in addition to the shares of common stock issuable upon settlement of such purchase contract, the related rights for the common stock, unless such rights under the future shareholder rights plan have separated from the common stock prior to the time of settlement of such purchase contract, in which case each fixed settlement rate shall be adjusted as discussed under “—(4) Debt or Asset Distributions” above on the date such rights separate from the common stock.

Adjustments to a fixed settlement rate will be calculated to the nearest 1/10,000th of a share. No adjustment to a fixed settlement rate will be required unless the adjustment would require an increase or decrease of at least one percent in such fixed settlement rate; provided, however, that if any adjustment is not required to be made because it would not change the fixed settlement rate by at least one percent, then the adjustment will be carried forward and taken into account in any subsequent adjustment; and provided further that any such adjustment of less than one percent that has not been made shall be made (x) upon the end of NEE’s fiscal year and (y) upon the applicable settlement date for a purchase contract.

No adjustment to a fixed settlement rate need be made if holders may participate in the transaction that would otherwise give rise to an adjustment, so long as the distributed assets or securities the holders would receive upon settlement of the purchase contracts, if convertible, exchangeable, or exercisable, are convertible, exchangeable or exercisable, as applicable, without any loss of rights or privileges for a period of at least 45 days following settlement of the purchase contracts.

The fixed settlement rates will not be adjusted:

•upon the issuance of any shares of NEE common stock pursuant to any present or future plan providing for the direct investment in NEE common stock or the reinvestment of dividends or interest payable on NEE’s securities or investment of additional optional amounts in shares of NEE common stock under any plan;

•upon the issuance of any shares of NEE common stock or options or rights to purchase those shares pursuant to any present or future employee, director or consultant compensation or other benefit plan or program of or assumed by NEE or any of its subsidiaries;

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•upon the issuance of any shares of NEE common stock pursuant to any option, warrant, right or any exercisable, exchangeable or convertible security outstanding as of the date the Equity Units were first issued;

•for a change in the par value or no par value of the common stock;

•for accumulated and unpaid dividends, other than as discussed under this “—Anti-dilution Adjustments” section; or

•upon the issuance of shares of NEE common stock or securities convertible into, or exercisable or exchangeable for, NEE common stock, in public or private transactions, for consideration in cash or property, at any price NEE deems appropriate.

NEE will be required, within ten business days following the adjustment of any fixed settlement rate, to provide written notice to the purchase contract agent of the occurrence of the adjustment and a statement in reasonable detail setting forth the method by which the adjustment to such fixed settlement rate was determined and setting forth the revised fixed settlement rates.

If an adjustment is made to a fixed settlement rate, an adjustment will also be made to the applicable market value solely to determine which of the clauses of the definition of settlement rate will be applicable on the Purchase Contract Settlement Date or any fundamental change early settlement date.

Termination of Purchase Contracts

The purchase contracts, and NEE’s rights and obligations and the rights and obligations of the holders of Equity Units under the purchase contracts, including the right and obligation to purchase NEE common stock and the right to receive accumulated contract adjustment payments or deferred contract adjustment payments, will immediately and automatically terminate upon the occurrence of certain events of bankruptcy, insolvency or reorganization with respect to NEE.

Upon any termination, the collateral agent will release the NEE Capital debentures underlying applicable ownership interests in NEE Capital debentures, the Treasury portfolio or the Treasury securities, as the case may be, held by it from the related pledge agreement to the purchase contract agent for distribution to the holders of Corporate Units and the Treasury Units. If a holder would otherwise have been entitled to receive less than $1,000 principal amount at maturity of any Treasury security upon termination of the purchase contract, the purchase contract agent will dispose of the security for cash and pay the cash to the holder. Upon any termination, however, the release and distribution may be subject to a delay. In the event that NEE becomes the subject of a proceeding under the U.S. Bankruptcy Code, the delay may occur as a result of the imposition of the automatic stay under the U.S. Bankruptcy Code and continue until the automatic stay has been lifted. NEE expects any such delay to be limited. Moreover, claims relating to the NEE Capital debentures will be subject to the equitable jurisdiction and powers of the bankruptcy court. For example, although NEE does not believe such an argument would prevail, a party in interest in a bankruptcy proceeding might successfully argue that the holders of Corporate Units or Treasury Units should be treated as equity holders, rather than creditors or owners of collateral, in the bankruptcy proceeding.

Pledged Securities and Pledge Agreements

The applicable ownership interests in the NEE Capital debentures, or, following a successful remarketing during the period for early remarketing, a special event redemption or a mandatory redemption, the applicable ownership interests in the Treasury portfolio, that are a component of the Corporate Units or, if substituted, the applicable ownership interest in the Treasury securities that are a component of the Treasury Units, collectively referred to as the “pledged securities,” will be pledged to NEE through the collateral agent, for the benefit of NEE, pursuant to a pledge agreement to secure the obligations of holders of Equity Units to purchase NEE common stock under the related purchase contracts. The rights of holders of Equity Units to the related pledged securities will be subject to NEE’s security interest created by such pledge agreement.

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No holder of Corporate Units or Treasury Units will be permitted to withdraw the pledged securities related to such Corporate Units or Treasury Units from the pledge arrangement except:

•in the case of Corporate Units, to substitute Treasury securities for the related NEE Capital debentures or the applicable ownership interest in the Treasury portfolio, as the case may be, as provided for under “Description of the Equity Units—Creating Treasury Units by Substituting a Treasury Security for a NEE Capital Debenture;”

•in the case of Treasury Units, to substitute NEE Capital debentures or the applicable ownership interest in the Treasury portfolio, as the case may be, for the related Treasury securities, as provided for under “Description of the Equity Units—Recreating Corporate Units;” or

•upon the termination, early settlement or cash settlement of the related purchase contracts.

Subject to the security interest and the terms of the respective purchase contract agreements and the pledge agreements, each holder of Corporate Units, unless the Treasury portfolio has replaced the NEE Capital debentures as a component of the Corporate Units, will be entitled through the purchase contract agent and the collateral agent to all of the proportional rights and preferences of the related NEE Capital debentures that are components of the Corporate Units, including distribution, voting, redemption, repayment and liquidation rights. Each holder of Treasury Units and each holder of the Corporate Units, if the Treasury portfolio has replaced the NEE Capital debentures as a component of the Corporate Units, will retain beneficial ownership of the related Treasury securities or the applicable ownership interest in the Treasury portfolio, as applicable, pledged in respect of the related purchase contracts. NEE will have no interest in the pledged securities other than its security interest.

Except as described under “Description of the Equity Units—Payments on Corporate Units and Treasury Units,” the collateral agent will, upon receipt of payments, if any, on the pledged securities, distribute the payments to the purchase contract agent, which will in turn distribute those payments to the persons in whose names the related Corporate Units or Treasury Units are registered at the close of business on the record date immediately preceding the date of payment.

Book-Entry Only System

The Depositary acts as securities depositary for the Equity Units. The Equity Units were issued only as fully-registered securities registered in the name of Cede & Co., the Depositary’s nominee. Fully-registered global security certificates, representing the total aggregate number of Equity Units, were issued and were deposited with the purchase contract agent, as custodian for the Depositary, and bear a legend regarding the restrictions on exchanges and registration of transfer referred to below.

In the event that the Depositary notifies NEE that it is unwilling or unable to continue as a depositary for the global security certificates and no successor depositary has been appointed within 90 days after this notice occurred and is continuing, certificates for the Equity Units will be printed and delivered in exchange for beneficial interests in the global security certificates. NEE may also decide to discontinue use of the system of book-entry transfers through the Depositary (or successor depositary). In that event, Equity Units certificates will be printed and delivered.

As long as the Depositary or its nominee is the registered owner of the global security certificates, the Depositary or the nominee, as the case may be, will be considered the sole owner and holder of the global security certificates and all Equity Units represented by these certificates for all purposes under the Equity Units and the purchase contract agreements. Except in the limited circumstances referred to above, owners of beneficial interests in global security certificates will not be entitled to have such global security certificates or the Equity Units represented by the global security certificates registered in their names, will not receive or be entitled to receive physical delivery of Equity Unit certificates in exchange for beneficial interests in global security certificates and will not be considered to be owners or holders of global security certificates or any Equity Units represented by these certificates for any purpose under the Equity Units or the purchase contract agreements.

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All payments on the Equity Units represented by the global security certificates and all transfers and deliveries of related NEE Capital debentures, Treasury securities, NEE common stock and the Treasury portfolio will be made to the Depositary or its nominee, as the case may be, as the holder of the securities.

Ownership of beneficial interests in the global security certificates is limited to participants or persons that may hold beneficial interests through institutions that have accounts with the Depositary or its nominee. Ownership of beneficial interests in global security certificates will be shown only on, and the transfer of those ownership interests will be effected only through, records maintained by the Depositary or its nominee, with respect to participants’ interests, or any participant, with respect to interests of persons held by the participant on their behalf. Procedures for settlement of purchase contracts on the Purchase Contract Settlement Date or upon early settlement will be governed by arrangements among the Depositary, participants and persons that may hold beneficial interests through participants designed to permit settlement without the physical movement of certificates. Payments, transfers, deliveries, exchanges and other matters relating to beneficial interests in global security certificates may be subject to various policies and procedures adopted by the Depositary from time to time. Neither NEE, NEE Capital nor any of their agents, nor the purchase contract agent nor any of its agents will have any responsibility or liability for any aspect of the Depositary’s or any participant’s records relating to, or for payments made on account of, beneficial interests in global security certificates, or for maintaining, supervising or reviewing any of the Depositary’s records or any participant’s records relating to these beneficial ownership interests.

Purchases of global securities under the DTC system must be made by or through direct participants, which will receive a credit for the global securities on DTC’s records. The ownership interest of each actual purchaser of each security (“Beneficial Owner”) is in turn to be recorded on the direct and indirect participants’ records. Beneficial Owners will not receive written confirmation from DTC of their purchase, but Beneficial Owners are expected to receive written confirmations providing details of the transaction, as well as periodic statements of their holdings, from the direct participant or indirect participant through which the Beneficial Owner entered into the transaction.

The information in this section concerning the Depositary and the Depositary’s book-entry system has been obtained from sources that NEE and NEE Capital believe to be reliable, but neither NEE nor NEE Capital take any responsibility for the accuracy of this information.

CERTAIN OTHER PROVISIONS OF THE PURCHASE CONTRACT
AGREEMENTS AND THE PLEDGE AGREEMENTS

This section briefly summarizes some of the material provisions of the purchase contract agreements and the pledge agreements that are not described elsewhere in this Part II. Corporate Units—Description of Equity Units. This summary does not contain a complete description of each purchase contract agreement and each pledge agreement. You should read this summary together with the purchase contract agreements and the pledge agreements for a complete understanding of all the provisions and for the definitions of some terms used in this summary. The purchase contract agreements and pledge agreements have been previously filed with the SEC and are exhibits to the Form 10-K. In addition, each purchase contract agreement is qualified as an indenture under the Trust Indenture Act of 1939 and is therefore subject to the provisions of the Trust Indenture Act of 1939. You should read the Trust Indenture Act of 1939 for a complete understanding of its provisions.

General

Except as described under “Description of the Purchase Contracts—Book-Entry Only System,” distributions on the Equity Units will be payable, purchase contracts will be settled (and documents related to the Equity Units and purchase contracts will be delivered), and transfers of the Equity Units will be registrable, at the office of the purchase contract agent in New York City. In addition, if all of the Equity Units do not remain in book-entry only form, payment of distributions on the Equity Units may be made, at NEE’s option, by check mailed to the address of the holder entitled to payment or by wire transfer to an account appropriately designated by the holder entitled to payment.

Shares of NEE common stock will be delivered on the Purchase Contract Settlement Date (or earlier upon early settlement), or, if the purchase contracts have terminated, the related pledged securities will be delivered

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(potentially after a delay as a result of the imposition of the automatic stay under the U.S. Bankruptcy Code (see “Description of the Purchase Contracts—Termination of Purchase Contracts”)), at the office of the purchase contract agent upon presentation and surrender of the related Equity Unit certificate.

If a holder of outstanding Corporate Units or Treasury Units fails to present and surrender the certificate evidencing the Corporate Units or Treasury Units to the purchase contract agent on or before the Purchase Contract Settlement Date (or earlier upon early settlement), the shares of NEE common stock issuable in settlement of the related purchase contract will be registered in the name of the purchase contract agent. The shares, together with any distributions thereon, will be held by the purchase contract agent as agent for the benefit of the holder until the applicable certificate is presented and surrendered or the holder provides satisfactory evidence that the certificate has been destroyed, mutilated, lost or stolen, together with any indemnity that may be required by the purchase contract agent and NEE.

If the purchase contracts have terminated prior to the Purchase Contract Settlement Date, the related pledged securities have been transferred to the purchase contract agent for distribution to the holders, and a holder fails to present and surrender the Equity Unit certificate evidencing the holder’s Corporate Units or Treasury Units to the purchase contract agent, the related pledged securities delivered to the purchase contract agent and payments on the pledged securities will be held by the purchase contract agent as agent for the benefit of the holder until the applicable certificate is presented and surrendered or the holder provides the evidence and the indemnity described above.

The purchase contract agent will have no obligation to invest or to pay interest on any amounts held by the purchase contract agent pending distribution to any holder.

No service charge will be made for any registration of transfer or exchange of the Equity Units, except for any tax or other governmental charge that may be imposed in connection therewith.

Modification

Each purchase contract agreement and pledge agreement contains provisions permitting NEE and the purchase contract agent, and in the case of the pledge agreements, the collateral agent, to modify the terms of the purchase contracts, such purchase contract agreement or the pledge agreement without the consent of the holders for any of the following purposes:

•to evidence the succession of another person to NEE’s obligations;

•to add to the covenants for the benefit of holders or to surrender any right or power of NEE under those agreements;

•to evidence and provide for the acceptance of appointment of a successor purchase contract agent or a successor collateral agent, custodial agent or securities intermediary;

•to cure any ambiguity, to correct or supplement any provisions that may be inconsistent with any other provision or to make such other provisions with respect to matters or questions arising under the purchase contract agreement and the pledge agreement, respectively, that do not adversely affect the interests of any holders in any material respect, provided that any amendment made solely to conform the provisions of such purchase contract agreement and the pledge agreement, respectively, to the description of the Equity Units contained in the prospectus supplement relating to the Equity Units, the purchase contracts and the other components of the Equity Units will not be deemed to adversely affect the interests of the holders; or

•in the case of the purchase contract agreement only, to make provision with respect to the rights of holders pursuant to adjustments due to consolidations, mergers or other reorganization events.

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Each purchase contract agreement and pledge agreement contains provisions permitting NEE and the purchase contract agent, and in the case of the pledge agreements, the collateral agent, with the consent of the holders of not less than a majority of the purchase contracts at the time outstanding, to modify the terms of such purchase contract, purchase contract agreement and pledge agreement. However, no such modification may, without the consent of the holder of each outstanding purchase contract affected by the modification:

•change any payment date;

•change the amount or type of pledged securities related to the purchase contract;

•impair the right of the holder of any Equity Unit to receive distributions on the pledged securities or otherwise adversely affect the holder’s rights in or to the pledged securities;

•reduce any contract adjustment payments or any deferred contract adjustment payments, or change the place or currency of payment;

•impair the right to institute suit for the enforcement of the purchase contract, any contract adjustment payments or any deferred contract adjustment payments;

•except as required pursuant to any anti-dilution adjustment, reduce the number of shares of NEE common stock or the amount of any other property purchasable under a purchase contract, increase the price to purchase NEE common stock or any other property upon settlement of any purchase contract, change the Purchase Contract Settlement Date or the right to early settlement or fundamental change early settlement or otherwise adversely affect the holder’s rights under a purchase contract in any material respect; or

•reduce the percentage of outstanding purchase contracts the consent of the holders of which is required for the modification or amendment of the provisions of the purchase contracts, the purchase contract agreements or the pledge agreements.

If any amendment or proposal referred to above would adversely affect only the Corporate Units or the Treasury Units, then only the affected class of holders will be entitled to vote on the amendment or proposal and the amendment or proposal will not be effective except with the consent of the holders of not less than a majority of the affected class or, if referred to in the seven preceding bullet points, all of the holders of the affected class.

No Consent to Assumption

Each holder of Corporate Units or Treasury Units, by acceptance of those securities, will under the terms of the purchase contract agreements and the Corporate Units or Treasury Units, as applicable, be deemed expressly to have withheld any consent to the assumption (i.e., affirmance) of the related purchase contracts by NEE or its trustee if NEE becomes the subject of a case under the U.S. Bankruptcy Code.

Consolidation, Merger, Sale or Conveyance

NEE covenanted in the purchase contract agreements that it will not merge or consolidate with or into any other entity or sell, assign, transfer, lease or convey all or substantially all of its properties and assets to any person or entity, unless:

•NEE is the continuing entity, or the successor entity is an entity organized and existing under the laws of the United States, any state thereof or the District of Columbia and expressly assumes NEE’s obligations under the purchase contracts, the purchase contract agreements, the pledge agreements, the guarantee agreement and each remarketing agreement; and

•NEE or the successor entity is not, immediately after the merger, consolidation, sale, assignment, transfer, lease or conveyance, in default of its payment obligations under the purchase contracts, the

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purchase contract agreements, the pledge agreements, the guarantee agreement or each remarketing agreement or in material default in the performance of any of its other obligations under these agreements.

Title

NEE, NEE Capital, the purchase contract agent, the collateral agent and any agent of NEE, NEE Capital, the purchase contract agent or the collateral agent may treat the registered owner of an Equity Unit as the absolute owner of that Equity Unit for the purpose of making payments and settling the related purchase contracts and for all other purposes regardless of any notice to the contrary.

Replacement of Equity Unit Certificates

In the event that physical certificates have been issued, any mutilated Equity Unit certificate will be replaced by NEE at the expense of the holder upon surrender of the certificate to the purchase contract agent. Equity Units certificates that have been destroyed, lost or stolen will be replaced by NEE at the expense of the holder upon delivery to NEE and the purchase contract agent of evidence of the destruction, loss or theft satisfactory to NEE and the purchase contract agent. In the case of a destroyed, lost or stolen Equity Unit certificate, an indemnity satisfactory to NEE and the purchase contract agent may be required at the expense of the holder of the Equity Units evidenced by the certificate before a replacement will be issued.

Notwithstanding the foregoing, NEE will not be obligated to issue any certificates for Corporate Units or Treasury Units on or after

•the business day immediately preceding the earliest of

•any early settlement date,

•any fundamental change early settlement date, or

•the Purchase Contract Settlement Date or

•the date on which the purchase contracts have terminated.

Each purchase contract agreement provides that, in lieu of the delivery of a replacement Equity Unit certificate following the Purchase Contract Settlement Date, the purchase contract agent, upon delivery of the evidence and indemnity described above, will deliver NEE common stock issuable pursuant to the purchase contracts included in Corporate Units or Treasury Units evidenced by the certificate, or, if the purchase contracts have terminated prior to the Purchase Contract Settlement Date, transfer the pledged securities included in Corporate Units or Treasury Units evidenced by the certificate.

Defaults under the Purchase Contract Agreements

Within 90 days after the occurrence of any default by NEE in any of its obligations under a purchase contract agreement of which the purchase contract agent has received written notice at the corporate trust office of the purchase contract agent, the purchase contract agent will give notice of such default to the holders of the related Equity Units unless such default has been cured or waived. Except for a default in any payment obligation under a purchase contract agreement, the purchase contract agent will be protected in withholding such notice if and so long as a responsible officer of the purchase contract agent in good faith determines that the withholding of such notice is in the interests of the holders of Equity Units.

The purchase contract agent is not required to enforce any of the provisions of a purchase contract agreement against NEE. Each holder of Equity Units shall have the right to institute suit for the enforcement of any payment of contract adjustment payments then due and payable and the right to purchase NEE common stock as provided in such holder’s purchase contracts and generally exercise any other rights and remedies provided by law.

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The holders of a majority of the outstanding purchase contracts under the related purchase contract agreement voting as one class may waive any past default by NEE and its consequences, except a default (1) in any payment on any Equity Unit or (2) in respect of a provision of such purchase contract agreement which cannot be modified or amended without the consent of the holder of each outstanding Equity Unit affected.

The Trust Indenture Act of 1939 requires NEE to provide annually to the purchase contract agent a certificate of one of its principal officers as to NEE’s compliance with all conditions and covenants in a purchase contract agreement.

Governing Law

The purchase contract agreements, the pledge agreements and the purchase contracts are governed by, and will be interpreted in accordance with, the laws of the State of New York without regard to New York’s conflict of laws principles, except to the extent that the laws of any other jurisdiction are mandatorily applicable.

Information Concerning the Purchase Contract Agent

The Bank of New York Mellon is the purchase contract agent. The purchase contract agent acts as the agent for the holders of Corporate Units and the Treasury Units from time to time. The purchase contract agreements do not obligate the purchase contract agent to exercise any discretionary actions in connection with a default under the terms of the Corporate Units and the Treasury Units or a purchase contract agreement.

The purchase contract agreements contain provisions limiting the liability of the purchase contract agent. The purchase contract agreements contain provisions under which the purchase contract agent may resign or be replaced. This resignation or replacement would be effective upon the appointment of a successor.

The Bank of New York Mellon also acts, and may act, as trustee under various indentures, trusts and guarantees of NEE and its affiliates, including as indenture trustee, security registrar and paying agent under the indenture and as guarantee trustee under the guarantee agreement. NEE and its affiliates maintain various banking and trust relationships with The Bank of New York Mellon.

Information Concerning the Collateral Agent

Deutsche Bank Trust Company Americas is the collateral agent. The collateral agent will act solely as NEE’s agent and will not assume any obligation or relationship of agency or trust for or with any of the holders of Corporate Units and Treasury Units except for the obligations owed by a pledgee of property to the owner of the property under the pledge agreement and applicable law.

The pledge agreements contain provisions limiting the liability of the collateral agent. The pledge agreements contain provisions under which the collateral agent may resign or be replaced. This resignation or replacement would be effective upon the appointment of a successor.

NEE and its affiliates maintain various banking and trust relationships with Deutsche Bank Trust Company Americas and its affiliates.

Miscellaneous

NEE will pay all fees and expenses related to the retention of the collateral agent and the enforcement by the purchase contract agent of the rights of the holders of the Equity Units.

Holders that elect to substitute the related pledged securities, thereby creating Treasury Units or recreating Corporate Units, will be responsible for any fees or expenses payable in connection with the substitution, as well as any commissions, fees or other expenses incurred in acquiring the pledged securities to be substituted, and NEE will not be responsible for any of those fees or expenses.

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DESCRIPTION OF THE NEE CAPITAL DEBENTURES

This section briefly summarizes some of the terms of the NEE Capital debentures and some of the provisions of the indenture. This summary does not contain a complete description of the NEE Capital debentures or the indenture referred to below. You should read this summary together with the indenture and the officer’s certificate creating the NEE Capital debentures for a complete understanding of all the provisions of the NEE Capital debentures and for the definitions of some terms used in this summary. The indenture and the officer’s certificates have been previously filed with the SEC and are exhibits to the Form 10-K. In addition, the indenture is qualified under the Trust Indenture Act of 1939 and is therefore subject to the provisions of the Trust Indenture Act of 1939. You should read the Trust Indenture Act of 1939 for a complete understanding of its provisions.

General

NEE Capital issued

•$1,500,000,000 in aggregate principal amount of the NEE Capital Series J Debentures due September 1, 2024 which are a component of the 4.872% Corporate Units,

•$2,500,000,000 in aggregate principal amount of the NEE Capital Series K Debentures due March 1, 2025 which are a component of the 5.279% Corporate Units, and

•$2,000,000,000 in aggregate principal amount of the NEE Capital Series L Debentures due September 1, 2025 which are a component of the 6.219% Corporate Units,

in each case under an indenture, dated as of June 1, 1999, as amended, referred to as the “indenture,” between NEE Capital and The Bank of New York Mellon, as indenture trustee. An officer’s certificate supplemented the indenture and created the specific terms of each series of the NEE Capital debentures. In addition to acting as purchase contract agent with respect to the Equity Units, The Bank of New York Mellon acts as indenture trustee, security registrar and paying agent under the indenture and as guarantee trustee under the guarantee agreement with respect to the NEE Capital debentures. Under the indenture, NEE Capital may issue an unlimited amount of additional debt securities. The NEE Capital debentures and all other debentures, notes or other debt of NEE Capital issued previously or hereafter under the indenture are collectively referred to as the “Senior Debt Securities.”

The indenture provides that NEE Capital may not grant a lien on the capital stock of any of its majority-owned subsidiaries which shares of capital stock NEE Capital now or hereafter directly owns to secure indebtedness of NEE Capital without similarly securing the NEE Capital debentures, with certain exceptions. However, the indenture does not limit the aggregate amount of indebtedness that NEE Capital and its subsidiaries may issue, guarantee or otherwise incur nor does it limit the ability of NEE Capital’s subsidiaries to grant a lien on any of their assets, including the capital stock of their respective subsidiaries. The guarantee agreement referred to below under “—Mandatory Redemption” does not limit the aggregate amount of indebtedness NEE and its subsidiaries may issue, guarantee or otherwise incur.

NEE Capital’s corporate parent, NEE, absolutely, irrevocably and unconditionally guarantees the payment of principal, interest and premium, if any, on the NEE Capital debentures. The NEE Capital debentures and the guarantee are unsecured and unsubordinated and rank equally with other unsecured and unsubordinated indebtedness from time to time outstanding of NEE Capital and NEE, respectively. See “Description of NEE Guarantee” below.

Unless an earlier redemption has occurred, the entire principal amount of the NEE Capital debentures will mature and become due and payable, together with any accrued and unpaid interest, on the NEE Capital Debenture Maturity Date (as defined in Annex A). Except as described below under “—Mandatory Redemption” and except for a special event redemption as described below under “—Special Event Redemption,” the NEE Capital debentures will not be redeemable by NEE Capital.

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NEE Capital debentures which are a component of the Corporate Units were issued in certificated form, in denominations of $1,000 and integral multiples of $1,000, without coupons; provided, however, that upon release by the collateral agent of NEE Capital debentures underlying the applicable ownership interests in the NEE Capital debentures pledged to secure the Corporate Units holders’ obligations to purchase NEE common stock under the related purchase contracts (other than any release of the NEE Capital debentures in connection with the creation of Treasury Units, an early settlement with separate cash, an early settlement upon a fundamental change, or a remarketing, each as described under “Description of the Purchase Contracts”), the NEE Capital debentures will be issuable in denominations of $50 principal amount and integral multiples thereof. The NEE Capital debentures may be transferred or exchanged, without service charge but upon payment of any taxes or other governmental charges payable in connection with the transfer or exchange, at the office described below.

Payments on NEE Capital debentures issued as a global security will be made to the Depositary, a successor depositary or, in the event that no depositary is used, to a paying agent for the NEE Capital debentures. Principal and interest with respect to certificated NEE Capital debentures will be payable, the transfer of the NEE Capital debentures will be registrable and NEE Capital debentures will be exchangeable for NEE Capital debentures of a like aggregate principal amount in denominations of $1,000 and integral multiples of $1,000 (unless the NEE Capital debentures have previously been issued in denominations of $50 and integral multiples thereof, in which case debentures will be exchangeable for a like aggregate principal amount in denominations of $50 and integral multiples of $50), at the office or agency maintained by NEE Capital for this purpose in New York City. However, at NEE Capital’s option, payment of interest may be made by check mailed to the address of the holder entitled to payment or by wire transfer to an account appropriately designated by the holder entitled to payment.

Each Corporate Unit includes a 5% undivided beneficial ownership interest in a NEE Capital debenture in the principal amount of $1,000 that corresponds to the stated amount of $50 per Corporate Unit.

The indenture trustee is initially the security registrar and the paying agent for the NEE Capital debentures. All transactions with respect to the NEE Capital debentures, including registration, transfer and exchange of the NEE Capital debentures, will be handled by the security registrar at an office in New York City designated by NEE Capital. NEE Capital has initially designated the corporate trust office of the indenture trustee as that office. In addition, holders of NEE Capital debentures should address any notices to NEE Capital regarding the NEE Capital debentures to that office. NEE Capital will notify holders of NEE Capital debentures of any change in the location of that office.

Interest and Payment

Each NEE Capital debenture bears interest initially at the respective Initial Interest Rate (as defined in Annex A) per year from the original issuance date to, but excluding, the reset effective date or, if no successful remarketing of the NEE Capital debentures of such series occurs, the respective NEE Capital Debenture Maturity Date. On or prior to the reset effective date, interest payments will be payable quarterly in arrears on each March 1, June 1, September 1 and December 1, each a “quarterly interest payment date,” commencing on the Initial Payment Date for such NEE Capital debentures. In addition, if the reset effective date falls on a day that is not also a quarterly interest payment date, holders of NEE Capital debentures will receive on the reset effective date a payment of accrued and unpaid interest from the most recent quarterly interest payment date to, but excluding, the reset effective date. In addition, for U.S. federal income tax purposes OID will accrue on the NEE Capital debentures. See “United States Federal Income Tax Discussion—U.S. Holders—NEE Capital Debentures—Original Issue Discount.”

The interest rate on the NEE Capital debentures will be reset to the reset rate upon a successful remarketing as described above under “Description of the Purchase Contracts—Remarketing.” The reset rate will become effective on the reset effective date, which is three business days immediately following a successful remarketing, unless the remarketing is successful within five business days of the next succeeding interest payment date, in which case such interest payment date will be the reset effective date; provided that in the event of a successful remarketing during the final three-day remarketing period, the reset effective date will be the Purchase Contract Settlement Date. Following a successful remarketing of the NEE Capital debentures, the NEE Capital debentures will bear interest from the reset effective date at the reset rate to, but excluding, the NEE Capital Debenture Maturity Date. From the reset effective date, interest payments on all NEE Capital debentures will be paid semi-annually in

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arrears on interest payment dates to be selected by NEE Capital. Semi-annual interest payments will include interest accrued from and including the immediately preceding semi-annual interest payment date or, in the case of the first semi-annual interest payment date following the reset effective date, from the reset effective date.

If no successful remarketing of the NEE Capital debentures occurs, the interest rate on the NEE Capital debentures will not be reset and interest payments on all NEE Capital debentures will remain payable quarterly in arrears on the originally-scheduled quarterly interest payment dates.

The amount of interest payable for any period will be computed on the basis of a 360-day year consisting of twelve 30-day months. The amount of interest payable for any period shorter than a full quarterly or semi-annual period for which interest is computed will be computed on the basis of the number of days in the period using 30-day calendar months. Interest on the NEE Capital debentures will be payable to the holders of NEE Capital debentures as they appear on the books and records of the securities registrar on the relevant record dates which, as long as all of the NEE Capital debentures remain in certificated form and are held by the purchase contract agent or are held in book-entry only form, will be one business day prior to the relevant payment date. In the event that NEE Capital debentures remain in certificated form but all are not held by the purchase contract agent or are not held in book-entry only form, NEE Capital shall have the right to select relevant record dates, which shall be at least one business day but no more than 60 business days prior to the relevant payment dates, and to make payments by check mailed to the address of the holder as of the relevant record date or by wire transfer to an account appropriately designated by the holder entitled to payment. In the event that any date on which interest is payable on the NEE Capital debentures is not a business day, then payment of the interest payable on that date will be made on the next succeeding day which is a business day, and no interest or payment will be paid in respect of the delay. However, if that business day is in the next succeeding calendar year, that payment will be made on the immediately preceding business day, in each case with the same force and effect as if made on the scheduled payment date.

Market Reset Rate

The reset rate will be equal to the rate that is sufficient to allow a successful remarketing of the NEE Capital debentures and will be determined by the remarketing agents. In the case of a reset prior to the final three-day remarketing period, which rate would be effective on the third day following the date of such successful remarketing, unless the remarketing is successful within five business days of the next succeeding interest payment date in which case such interest payment date will be the reset effective date, the reset rate will be the rate determined by the remarketing agents as the rate the NEE Capital debentures should bear in order for the NEE Capital debentures that are components of the Corporate Units to have an aggregate market value on the reset effective date of at least 100% of the Treasury portfolio purchase price described under “Description of the Purchase Contracts—Remarketing” plus the aggregate separate NEE Capital debenture purchase price plus the remarketing fee. In the case of a reset during the final three-day remarketing period, the reset rate will be the rate determined by the remarketing agents as the rate the NEE Capital debentures should bear in order for each NEE Capital debenture being remarketed to have an aggregate market value of at least 100% of the principal amount of the NEE Capital debenture plus the remarketing fee. The reset rate will in no event exceed the maximum rate, if any, permitted by applicable law.

If the NEE Capital debentures are not successfully remarketed, the interest rate will not be reset and the NEE Capital debentures will continue to bear interest at the Initial Interest Rate, payable quarterly in arrears.

Optional Remarketing

On or prior to the second business day, but no earlier than the fifth business day immediately preceding the first of the three sequential remarketing days of any three-day remarketing period, holders of NEE Capital debentures that are not components of Corporate Units may elect to have their NEE Capital debentures remarketed in the same manner as NEE Capital debentures that are a component of Corporate Units by delivering their NEE Capital debentures, along with a notice of this election to the custodial agent. By delivering such notice, holders will elect to have their NEE Capital debentures remarketed in each remarketing attempt during the applicable three-day remarketing period. The custodial agent will hold the NEE Capital debentures in an account separate from the collateral account in which the pledged securities will be held. Holders of NEE Capital debentures electing to have those NEE Capital debentures remarketed will also have the right to withdraw the election on or prior to the second

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business day immediately preceding the first of the three sequential remarketing days of the applicable three-day remarketing period. If each remarketing attempt during the applicable three-day remarketing period is unsuccessful, the custodial agent will return the NEE Capital debentures that are not a component of the Corporate Units to their holders and these holders may elect to have their NEE Capital debentures included in the remarketings during each subsequent three-day remarketing period by redelivering their NEE Capital debentures and notice of election in the manner described in this paragraph. Holders of Treasury Units that are also holders of NEE Capital debentures that are not part of the Corporate Units may also participate in any remarketing by recreating Corporate Units from their Treasury Units on or prior to the second business day immediately prior to the first of the three sequential remarketing days of any three-day remarketing period.

Put Right Following Unsuccessful Final Remarketing

If the NEE Capital debentures have not been successfully remarketed prior to the Purchase Contract Settlement Date, holders of all NEE Capital debentures (including beneficial owners of NEE Capital debentures that are components of the Corporate Units) will have the right to put their NEE Capital debentures to NEE Capital on the Purchase Contract Settlement Date, upon at least two business days’ prior written notice to the purchase contract agent, for an amount equal to the put price. A holder of Corporate Units will be deemed to have automatically exercised this put right with respect to the NEE Capital debentures that are components of such Corporate Units as described under “Description of the Purchase Contracts—Remarketing,” unless the holder settles the related purchase contracts with separate cash as described under “Description of the Purchase Contracts—Early Settlement by Delivering Cash” and “—Notice to Settle with Cash.”

Mandatory Redemption

The following constitute “Guarantor Events” with respect to the NEE Capital debentures:

•the guarantee agreement, dated as of June 1, 1999, between NEE, as guarantor, and The Bank of New York Mellon, as guarantee trustee, ceases to be in full force and effect;

•a court issues a decree ordering or acknowledging the bankruptcy or insolvency of NEE, or appointing a custodian, receiver or other similar official for NEE, or ordering the winding up or liquidation of its affairs, and the decree remains in effect for 90 days; or

•NEE seeks or consents to relief under federal or state bankruptcy or insolvency laws, or to the appointment of a custodian, receiver or other similar official for NEE, or makes an assignment for the benefit of its creditors, or admits in writing that it is bankrupt or insolvent.

NEE Capital shall, if a Guarantor Event occurs and is continuing, redeem all of the outstanding NEE Capital debentures within 60 days after the occurrence of the Guarantor Event at a redemption price described below unless, within 30 days after the occurrence of the Guarantor Event, S&P Global Ratings, a division of S&P Global Inc., and Moody’s Investors Service, Inc. (if the outstanding NEE Capital debentures are then rated by those rating agencies, or, if the outstanding NEE Capital debentures are then rated by only one of those rating agencies, then such rating agency, or, if the outstanding NEE Capital debentures are not then rated by either one of those rating agencies but are then rated by one or more other nationally recognized rating agencies, then at least one of those other nationally recognized rating agencies) shall have reaffirmed in writing that, after giving effect to such Guarantor Event, the credit rating on the outstanding NEE Capital debentures is investment grade (i.e., in one of the four highest categories, without regard to subcategories within such rating categories, of such rating agency).

If a Guarantor Event occurs and NEE Capital is not required to redeem the outstanding NEE Capital debentures as described above, NEE Capital will provide to the indenture trustee and the holders of the outstanding NEE Capital debentures annual and quarterly reports containing the information that NEE Capital would be required to file with the SEC under Section 13 or Section 15(d) of the Securities Exchange Act of 1934 if it were subject to the reporting requirements of either of those Sections. If NEE Capital is, at that time, subject to the reporting requirements of either of those Sections, the filing of annual and quarterly reports with the SEC pursuant to either of those Sections will satisfy this requirement.

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If NEE Capital is required to redeem all of the outstanding NEE Capital debentures following a Guarantor Event:

•prior to the applicable Purchase Contract Settlement Date, if the purchase contracts have been previously or concurrently terminated as described under “Description of the Purchase Contracts—Termination of Purchase Contracts,” the mandatory redemption price will be equal to the principal amount of each NEE Capital debenture plus accrued and unpaid interest, if any, to, but excluding, the date of redemption;

•prior to the applicable Purchase Contract Settlement Date, if the purchase contracts have not been so previously or concurrently terminated, the mandatory redemption price will be equal to, for each NEE Capital debenture, the redemption amount described below under “—Special Event Redemption” plus accrued and unpaid interest, if any, to, but excluding, the date of redemption, and such redemption price will be distributed to the collateral agent, as described below under “—Special Event Redemption”; or

•on or after the applicable Purchase Contract Settlement Date, the mandatory redemption price will be equal to the principal amount of each NEE Capital debenture plus accrued and unpaid interest, if any, to, but excluding, the date of redemption.

Special Event Redemption

If a special event occurs and is continuing, NEE Capital may, at its option, redeem the NEE Capital debentures in whole but not in part at any time at a price, which is referred to as the “redemption price,” equal to, for each NEE Capital debenture, the redemption amount described below plus accrued and unpaid interest, if any, to, but excluding, the date of redemption. Installments of interest on NEE Capital debentures which are due and payable on or prior to a redemption date will be payable to the holders of NEE Capital debentures registered as such at the close of business on the relevant record dates. If, following the occurrence of a special event, NEE Capital exercises its option to redeem the NEE Capital debentures, the proceeds of the redemption will be payable in cash to the holders of NEE Capital debentures which are not part of Corporate Units. If the special event redemption occurs prior to a successful remarketing of the NEE Capital debentures, or if the NEE Capital debentures are not successfully remarketed prior to the Purchase Contract Settlement Date, the redemption price for the NEE Capital debentures that are components of the Corporate Units at the time of the special event redemption will be distributed to the collateral agent, who in turn will purchase the Treasury portfolio described below on behalf of the holders of Corporate Units and remit the remainder of the redemption price, if any, to the purchase contract agent for payment to the holders. Thereafter, the applicable ownership interests in the Treasury portfolio will be substituted for the applicable ownership interests in the NEE Capital debentures and will be pledged to NEE through the collateral agent to secure the Corporate Unit holders’ obligations to purchase NEE common stock under the purchase contracts.

“Special event” means either an accounting event or a tax event, each as defined below.

“Accounting event” means the receipt by the audit committee of NEE’s Board of Directors (or, if there is no such committee, by such Board of Directors) of a written report in accordance with Statement on Auditing Standards (“SAS”) No. 97, “Amendment to SAS No. 50—Reports on the Application of Accounting Principles,” from NEE’s independent auditors, provided at the request of NEE management, to the effect that, as a result of a change in accounting rules that becomes effective after the Closing Date, NEE must either (1) account for the purchase contracts as derivatives (or otherwise mark-to-market or measure the fair value of all or any portion of the purchase contracts with changes appearing in NEE’s income statement) or (2) account for the Equity Units using the if-converted method, and that such accounting treatment will cease to apply upon redemption of the NEE Capital debentures.

“Tax event” means the receipt by NEE Capital of an opinion of nationally recognized independent tax counsel experienced in such matters (which may be Morgan, Lewis & Bockius LLP or Squire Patton Boggs (US) LLP) to the effect that there is more than an insubstantial risk that interest payable by NEE Capital on the NEE

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Capital debentures would not be deductible, in whole or in part, by NEE Capital for U.S. federal income tax purposes as a result of any amendment to, change in, or announced proposed change in, the laws, or any regulations thereunder, of the United States or any political subdivision or taxing authority thereof or therein affecting taxation, any amendment to or change in an interpretation or application of any such laws or regulations by any legislative body, court, governmental agency or regulatory authority or any interpretation or pronouncement by any legislative body, court, governmental agency or regulatory authority that provides for a position with respect to any such laws or regulations that differs from the generally accepted position on the Tax Event Measurement Date (as defined in Annex A), which amendment, change or proposed change is effective or which interpretation or pronouncement is announced on or after the Tax Event Measurement Date.

“Redemption amount” means

•in the case of a special event redemption occurring prior to the earlier of (1) a successful remarketing or (2) the Purchase Contract Settlement Date, for each NEE Capital debenture, the product of the principal amount of that NEE Capital debenture and a fraction, the numerator of which is the Treasury portfolio purchase price and the denominator of which is the aggregate principal amount of the NEE Capital debentures included in Corporate Units on the special event redemption date, and

•in the case of a special event redemption occurring on or after the earlier of (1) a successful remarketing or (2) the Purchase Contract Settlement Date, for each NEE Capital debenture outstanding on the special event redemption date, the principal amount of the NEE Capital debenture.

Depending on the Treasury portfolio purchase price, the redemption amount could be less than or greater than the principal amount of the NEE Capital debentures.

As used in this context, “Treasury portfolio purchase price” means the lowest aggregate price quoted by a primary U.S. government securities dealer in New York City to the quotation agent on the third business day immediately preceding the special event redemption date for the purchase of the special event Treasury portfolio for settlement on the special event redemption date.

The Treasury portfolio to be purchased in connection with a special event redemption, or a special event Treasury portfolio, will consist of:

•U.S. Treasury securities (or principal or interest strips thereof) that mature on or prior to the Treasury Portfolio Maturity Deadline in an aggregate amount at maturity equal to the aggregate principal amount of the NEE Capital debentures which are a component of the Corporate Units; and

•with respect to each scheduled interest payment date on the NEE Capital debentures that occurs after the special event redemption date and on or prior to the Purchase Contract Settlement Date, U.S. Treasury securities (or principal or interest strips thereof) that mature on or prior to such scheduled interest payment date in an aggregate amount at maturity equal to the aggregate interest payment that would be due on the aggregate principal amount of the NEE Capital debentures which would have been components of the Corporate Units on that date (assuming no special event redemption) and assuming that interest accrued from and including the immediately preceding interest payment date to which interest has been paid.

Notice of any redemption will be mailed at least 30 days but not more than 60 days before the redemption date to each registered holder of NEE Capital debentures to be redeemed at its registered address. Unless NEE Capital defaults in payment of the redemption price, on and after the redemption date interest shall cease to accrue on the NEE Capital debentures. In the event any NEE Capital debentures are called for redemption, neither NEE Capital nor the indenture trustee will be required to register the transfer of or exchange the NEE Capital debentures to be redeemed.

Security and Ranking.  The NEE Capital debentures are unsecured obligations of NEE Capital. The indenture does not limit NEE Capital’s ability to provide security with respect to other Senior Debt Securities. All Senior Debt Securities issued under the indenture will rank equally and ratably with all other Senior Debt Securities

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issued under the Indenture, except to the extent that NEE Capital elects to provide security with respect to any Senior Debt Security (other than the NEE Capital debentures) without providing that security to all outstanding Senior Debt Securities in accordance with the Indenture. The NEE Capital debentures rank senior to any debt securities of NEE capital that are expressly subordinated by their terms. The indenture does not limit NEE Capital’s ability to issue other unsecured debt.

While NEE Capital is a holding company that derives substantially all of its income from its operating subsidiaries, NEE Capital’s subsidiaries are separate and distinct legal entities and have no obligation to make any payments on the Senior Debt Securities or to make any funds available for such payment. Therefore, the Senior Debt Securities will effectively be subordinated to all indebtedness and other liabilities, including trade payables, debt and preferred stock, incurred or issued by NEE Capital’s subsidiaries. In addition to trade liabilities, many of NEE Capital’s operating subsidiaries incur debt in order to finance their business activities. All of this indebtedness will effectively be senior to the Senior Debt Securities. The Indenture does not place any limit on the amount of liabilities, including debt or preferred stock, that NEE Capital’s subsidiaries may issue, guarantee or incur.

Payment and Paying Agents.  On each interest payment date NEE Capital will pay interest on each NEE Capital debenture to the person in whose name that NEE Capital debenture is registered as of the close of business on the record date relating to that interest payment date. However, on the date that the NEE Capital Debentures mature, NEE Capital will pay the interest to the person to whom it pays the principal. Also, if NEE Capital has defaulted in the payment of interest on any NEE Capital debenture, it may pay that defaulted interest to the registered owner of that NEE Capital debenture:

(1)    as of the close of business on a date that the indenture trustee selects, which may not be more than 15 days or less than 10 days before the date that NEE Capital proposes to pay the defaulted interest, or

(2)    in any other lawful manner that does not violate the requirements of any securities exchange on which that Offered Senior Debt Security is listed and that the indenture trustee believes is practicable. (Indenture, Section 307).

The principal, premium, if any, and interest on the NEE Capital debentures at maturity will be payable when such NEE Capital debentures are presented at the main corporate trust office of The Bank of New York Mellon, as paying agent, in New York City. NEE Capital may change the place of payment on the NEE Capital debentures, appoint one or more additional paying agents, including NEE Capital, and remove any paying agent. (Indenture, Section 602).

Transfer and Exchange. NEE Capital debentures may be transferred or exchanged at the main corporate trust office of The Bank of New York Mellon, as security registrar, in New York City. NEE Capital may change the place for transfer and exchange of the NEE Capital debentures and may designate one or more additional places for that transfer and exchange.

There will be no service charge for any transfer or exchange of the NEE Capital debentures. However, NEE Capital may require payment of any tax or other governmental charge in connection with any transfer or exchange of the NEE Capital debentures.

NEE Capital will not be required to transfer or exchange any NEE Capital debenture selected for redemption. Also, NEE Capital will not be required to transfer or exchange any NEE Capital debenture during a period of 15 days before notice is to be given identifying the NEE Capital debentures selected to be redeemed. (Indenture, Section 305).

Defeasance.  NEE Capital may, at any time, elect to have all of its obligations discharged with respect to all or a portion of any Senior Debt Securities. To do so, NEE Capital must irrevocably deposit with the indenture trustee or any paying agent, in trust:

(1)    money in an amount that will be sufficient to pay all or that portion of the principal, premium, if any, and interest due and to become due on those Senior Debt Securities, on or prior to their maturity, or

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(2)    in the case of a deposit made prior to the maturity of that series of Senior Debt Securities,

(a)    direct obligations of, or obligations unconditionally guaranteed by, the United States and entitled to the benefit of its full faith and credit that do not contain provisions permitting their redemption or other prepayment at the option of their issuer, and

(b)    certificates, depositary receipts or other instruments that evidence a direct ownership interest in those obligations or in any specific interest or principal payments due in respect of those obligations that do not contain provisions permitting their redemption or other prepayment at the option of their issuer,

the principal of and the interest on which, when due, without any regard to reinvestment of that principal or interest, will provide money that, together with any money deposited with or held by the indenture trustee, will be sufficient to pay all or that portion of the principal, premium, if any, and interest due and to become due on those Senior Debt Securities, on or prior to their maturity, or

(3)    a combination of  (1) and (2) that will be sufficient to pay all or that portion of the principal, premium, if any, and interest due and to become due on those Senior Debt Securities, on or prior to their maturity. (Indenture, Section 701).

Limitation on Liens.  So long as any Senior Debt Securities remain outstanding, NEE Capital will not secure any indebtedness with a lien on any shares of the capital stock of any of its majority-owned subsidiaries, which shares of capital stock NEE Capital now or hereafter directly owns, unless NEE Capital equally secures all Senior Debt Securities. However, this restriction does not apply to or prevent:

(1)    any lien on capital stock created at the time NEE Capital acquires that capital stock, or within 270 days after that time, to secure all or a portion of the purchase price for that capital stock,

(2)    any lien on capital stock existing at the time NEE Capital acquires that capital stock (whether or not NEE Capital assumes the obligations secured by the lien and whether or not the lien was created in contemplation of the acquisition),

(3)    any extensions, renewals or replacements of the liens described in (1) and (2) above, or of any indebtedness secured by those liens; provided, that,

(a)    the principal amount of indebtedness secured by those liens immediately after the extension, renewal or replacement may not exceed the principal amount of indebtedness secured by those liens immediately before the extension, renewal or replacement, and

(b)    the extension, renewal or replacement lien is limited to no more than the same proportion of all shares of capital stock as were covered by the lien that was extended, renewed or replaced, or

(4)    any lien arising in connection with court proceedings; provided that, either

(a)    the execution or enforcement of that lien is effectively stayed within 30 days after entry of the corresponding judgment (or the corresponding judgment has been discharged within that 30 day period) and the claims secured by that lien are being contested in good faith by appropriate proceedings,

(b)    the payment of that lien is covered in full by insurance and the insurance company has not denied or contested coverage, or

(c)    so long as that lien is adequately bonded, any appropriate legal proceedings that have been duly initiated for the review of the corresponding judgment, decree or order have not been fully terminated or the periods within which those proceedings may be initiated have not expired.

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Liens on any shares of the capital stock of any of NEE Capital’s majority-owned subsidiaries, which shares of capital stock NEE Capital now or hereafter directly owns, other than liens described in (1) through (4) above, are referred to as “Restricted Liens.” The foregoing limitation does not apply to the extent that NEE Capital creates any Restricted Liens to secure indebtedness that, together with all other indebtedness of NEE Capital secured by Restricted Liens, does not at the time exceed 5% of NEE Capital’s Consolidated Capitalization. (Indenture, Section 608).

For this purpose, “Consolidated Capitalization” means the sum of:

(1)    Consolidated Shareholders’ Equity,

(2)    Consolidated Indebtedness for borrowed money (exclusive of any amounts which are due and payable within one year); and, without duplication, and

(3)    any preference or preferred stock of NEE Capital or any Consolidated Subsidiary which is subject to mandatory redemption or sinking fund provisions.

The term “Consolidated Shareholders’ Equity” as used above means the total assets of NEE Capital and its Consolidated Subsidiaries less all liabilities of NEE Capital and its Consolidated Subsidiaries. As used in this definition, the term “liabilities” means all obligations which would, in accordance with generally accepted accounting principles, be classified on a balance sheet as liabilities, including without limitation:

(1)    indebtedness secured by property of NEE Capital or any of its Consolidated Subsidiaries whether or not NEE Capital or such Consolidated Subsidiary is liable for the payment thereof unless, in the case that NEE Capital or such Consolidated Subsidiary is not so liable, such property has not been included among the assets of NEE Capital or such Consolidated Subsidiary on such balance sheet,

(2)    deferred liabilities, and

(3)    indebtedness of NEE Capital or any of its Consolidated Subsidiaries that is expressly subordinated in right and priority of payment to other liabilities of NEE Capital or such Consolidated Subsidiary.

As used in this definition, “liabilities” includes preference or preferred stock of NEE Capital or any Consolidated Subsidiary only to the extent of any such preference or preferred stock that is subject to mandatory redemption or sinking fund provisions.

The term “Consolidated Indebtedness” means total indebtedness as shown on the consolidated balance sheet of NEE Capital and its Consolidated Subsidiaries.

The term “Consolidated Subsidiary,” means at any date any direct or indirect majority-owned subsidiary whose financial statements would be consolidated with those of NEE Capital in NEE Capital’s consolidated financial statements as of such date in accordance with generally accepted accounting principles. (Indenture, Section 608).

The foregoing limitation does not limit in any manner the ability of:

(1)    NEE Capital to place liens on any of its assets other than the capital stock of directly held, majority-owned subsidiaries,

(2)    NEE Capital or NEE to cause the transfer of its assets or those of its subsidiaries, including the capital stock covered by the foregoing restrictions,

(3)    NEE to place liens on any of its assets, or

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(4)    any of the direct or indirect subsidiaries of NEE Capital or NEE (other than NEE Capital) to place liens on any of their assets.

Consolidation, Merger, and Sale of Assets.  Under the Indenture, NEE Capital may not consolidate with or merge into any other entity or convey, transfer or lease its properties and assets substantially as an entirety to any entity, unless:

(1)    the entity formed by that consolidation, or the entity into which NEE Capital is merged, or the entity that acquires or leases NEE Capital’s properties and assets, is an entity organized and existing under the laws of the United States, any state or the District of Columbia and that entity expressly assumes NEE Capital’s obligations on all Senior Debt Securities and under the Indenture,

(2)    immediately after giving effect to the transaction, no event of default under the Indenture and no event that, after notice or lapse of time or both, would become an event of default under the Indenture exists, and

(3)    NEE Capital delivers an officer’s certificate and an opinion of counsel to the indenture trustee, as provided in the Indenture. (Indenture, Section 1101).

The Indenture does not restrict NEE Capital in a merger in which NEE Capital is the surviving entity.

Events of Default.  Each of the following is an event of default under the Indenture with respect to the Senior Debt Securities of any series:

(1)    failure to pay interest on the Senior Debt Securities of that series within 30 days after it is due,

(2)    failure to pay principal or premium, if any, on the Senior Debt Securities of that series when it is due,

(3)    failure to perform, or breach of, any other covenant or warranty in the Indenture, other than a covenant or warranty that does not relate to that series of Senior Debt Securities, that continues for 90 days after (i) NEE Capital receives written notice of such failure to comply from the indenture trustee or (ii) NEE Capital and the indenture trustee receive written notice of such failure to comply from the registered owners of at least 33% in principal amount of the Senior Debt Securities of that series,

(4)    certain events of bankruptcy, insolvency or reorganization of NEE Capital, or

(5)    any other event of default specified with respect to the Senior Debt Securities of that series. (Indenture, Section 801).

In the case of an event of default listed in item (3) above, the indenture trustee may extend the grace period. In addition, if registered owners of a particular series have given a notice of default, then registered owners of at least the same percentage of Senior Debt Securities of that series, together with the indenture trustee, may also extend the grace period. The grace period will be automatically extended if NEE Capital has initiated and is diligently pursuing corrective action. (Indenture, Section 801). An event of default with respect to the Senior Debt Securities of a particular series will not necessarily constitute an event of default with respect to Senior Debt Securities of any other series issued under the Indenture.

In addition to the events of default listed above, each of the following events will be an event of default under the indenture with respect to the NEE Capital debentures:

(1)    NEE consolidates with or merges into any other entity or conveys, transfers or leases substantially all of its properties and assets to any entity, unless

(a)    the entity formed by such consolidation or into which NEE is merged, or the entity to which NEE conveys, transfers or leases substantially all of its properties and assets is an entity organized and

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existing under the laws of the United States, any state thereof or the District of Columbia, and expressly assumes the obligations of NEE under the guarantee agreement; and

(b)    immediately after giving effect to such transaction, no event of default under the indenture and no event that, after notice or lapse of time or both, would become an event of default under the indenture, shall have occurred and be continuing; or

(2)    NEE Capital fails to redeem any of the NEE Capital debentures that it is required to redeem as described under “—Mandatory Redemption” above.

Remedies.  If an event of default applicable to the Senior Debt Securities of one or more series, but not applicable to all outstanding Senior Debt Securities, exists, then either (i) the indenture trustee or (ii) the registered owners of at least 33% in aggregate principal amount of the Senior Debt Securities of each of the affected series may declare the principal of and accrued but unpaid interest on all the Senior Debt Securities of that series to be due and payable immediately. (Indenture, Section 802). However, under the Indenture, some Senior Debt Securities may provide for a specified amount less than their entire principal amount to be due and payable upon that declaration. Such a Senior Debt Security is defined as a “Discount Security” in the Indenture.

If an event of default is applicable to all outstanding Senior Debt Securities, then either (i) the indenture trustee or (ii) the registered owners of at least 33% in aggregate principal amount of all outstanding Senior Debt Securities of all series, voting as one class, and not the registered owners of any one series, may make a declaration of acceleration. However, the event of default giving rise to the declaration relating to any series of Senior Debt Securities will be automatically waived, and that declaration and its consequences will be automatically rescinded and annulled, if, at any time after that declaration and before a judgment or decree for payment of the money due has been obtained:

(1)    NEE Capital pays or deposits with the indenture trustee a sum sufficient to pay:

(a)    all overdue interest on all Senior Debt Securities of that series,

(b)    the principal of and any premium on any Senior Debt Securities of that series that have become due for reasons other than that declaration, and interest that is then due,

(c)    interest on overdue interest for that series, and

(d)    all amounts then due to the indenture trustee under the Indenture, and

(2)    any other event of default with respect to the Senior Debt Securities of that series has been cured or waived as provided in the Indenture. (Indenture, Section 802).

Other than its obligations and duties in case of an event of default under the Indenture, the indenture trustee is not obligated to exercise any of its rights or powers under the Indenture at the request or direction of any of the registered owners of the Senior Debt Securities, unless those registered owners offer reasonable indemnity to the indenture trustee. (Indenture, Section 903). If they provide this reasonable indemnity, the registered owners of a majority in principal amount of any series of Senior Debt Securities will have the right to direct the time, method and place of conducting any proceeding for any remedy available to the indenture trustee, or exercising any trust or power conferred on the indenture trustee, with respect to the Senior Debt Securities of that series. However, if an event of default under the Indenture relates to more than one series of Senior Debt Securities, only the registered owners of a majority in aggregate principal amount of all affected series of Senior Debt Securities, considered as one class, will have the right to make that direction. Also, the direction must not violate any law or the Indenture, and may not expose the indenture trustee to personal liability in circumstances where the indemnity would not, in the indenture trustee’s sole discretion, be adequate, and the indenture trustee may take any other action that it deems proper and not inconsistent with such direction. (Indenture, Section 812).

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A registered owner of a Senior Debt Security has the right to institute a suit for the enforcement of payment of the principal of or premium, if any, or interest on that Senior Debt Security on or after the applicable due date specified in that Senior Debt Security. (Indenture, Section 808). No registered owner of Senior Debt Securities of any series will have any other right to institute any proceeding under the Indenture, or any other remedy under the Indenture, unless:

(1)    that registered owner has previously given to the indenture trustee written notice of a continuing event of default with respect to the Senior Debt Securities of that series,

(2)    the registered owners of a majority in aggregate principal amount of the outstanding Senior Debt Securities of all series in respect of which an event of default under the Indenture exists, considered as one class, have made written request to the indenture trustee to institute that proceeding in its own name as trustee, and have offered reasonable indemnity to the indenture trustee against related costs, expenses and liabilities,

(3)    the indenture trustee for 60 days after its receipt of that notice, request and offer of indemnity has failed to institute any such proceeding, and

(4)    no direction inconsistent with that request was given to the indenture trustee during this 60 day period by the registered owners of a majority in aggregate principal amount of the outstanding Senior Debt Securities of all series in respect of which an event of default under the Indenture exists, considered as one class. (Indenture, Section 807).

NEE Capital is required to deliver to the indenture trustee an annual statement as to its compliance with all conditions and covenants under the Indenture. (Indenture, Section 606).

Modification and Waiver.  Without the consent of any registered owner of Senior Debt Securities, NEE Capital and the indenture trustee may amend or supplement the Indenture for any of the following purposes:

(1)    to provide for the assumption by any permitted successor to NEE Capital of NEE Capital’s obligations under the Indenture and the Senior Debt Securities in the case of a merger or consolidation or a conveyance, transfer or lease of NEE Capital’s properties and assets substantially as an entirety,

(2)    to add covenants of NEE Capital or to surrender any right or power conferred upon NEE Capital by the Indenture,

(3)    to add any additional events of default,

(4)    to change, eliminate or add any provision of the Indenture, provided that if that change, elimination or addition will materially adversely affect the interests of the registered owners of Senior Debt Securities of any series or tranche, that change, elimination or addition will become effective with respect to that particular series or tranche only

(a)    when the required consent of the registered owners of Senior Debt Securities of that particular series or tranche has been obtained, or

(b)    when no Senior Debt Securities of that particular series or tranche remain outstanding under the Indenture,

(5)    to provide collateral security for all but not a part of the Senior Debt Securities,

(6)    to create the form or terms of Senior Debt Securities of any other series or tranche,

(7)    to provide for the authentication and delivery of bearer securities and the related coupons and for other matters relating to those bearer securities,

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(8)    to accept the appointment of a successor Indenture Trustee with respect to the Senior Debt Securities of one or more series and to change any of the provisions of the Indenture as necessary to provide for the administration of the trusts under the Indenture by more than one trustee,

(9)    to add procedures to permit the use of a non-certificated system of registration for all, or any series or tranche of, the Senior Debt Securities,

(10)    to change any place where

(a)    the principal of and premium, if any, and interest on all, or any series or tranche of, Senior Debt Securities are payable,

(b)    all, or any series or tranche of, Senior Debt Securities may be surrendered for registration, transfer, or exchange, and

(c)    notices and demands to or upon NEE Capital in respect of Senior Debt Securities and the Indenture may be served, or

(11)    to cure any ambiguity or inconsistency or to add or change any other provisions with respect to matters and questions arising under the Indenture, provided those changes or additions may not materially adversely affect the interests of the registered owners of Senior Debt Securities of any series or tranche. (Indenture, Section 1201).

The registered owners of a majority in aggregate principal amount of the Senior Debt Securities of all series then outstanding may waive compliance by NEE Capital with certain restrictive provisions of the Indenture. (Indenture, Section 607). The registered owners of a majority in principal amount of the outstanding Senior Debt Securities of any series may waive any past default under the Indenture with respect to that series, except a default in the payment of principal, premium, if any, or interest and a default with respect to certain restrictive covenants or provisions of the Indenture that cannot be modified or amended without the consent of the registered owner of each outstanding Senior Debt Security of that series affected. (Indenture, Section 813).

In addition to any amendments described above, if the Trust Indenture Act of 1939 is amended after the date of the Indenture in a way that requires changes to the Indenture or in a way that permits changes to, or the elimination of, provisions that were previously required by the Trust Indenture Act of 1939, the Indenture will be deemed to be amended to conform to that amendment of the Trust Indenture Act of 1939 or to make those changes, additions or eliminations. NEE Capital and the indenture trustee may, without the consent of any registered owners, enter into supplemental indentures to make that amendment. (Indenture, Section 1201).

Except for any amendments described above, the consent of the registered owners of a majority in aggregate principal amount of the Senior Debt Securities of all series then outstanding, considered as one class, is required for all other modifications to the Indenture. However, if less than all of the series of Senior Debt Securities outstanding are directly affected by a proposed supplemental indenture, then the consent only of the registered owners of a majority in aggregate principal amount of outstanding Senior Debt Securities of all directly affected series, considered as one class, is required. But, if NEE Capital issues any series of Senior Debt Securities in more than one tranche and if the proposed supplemental indenture directly affects the rights of the registered owners of Senior Debt Securities of less than all of those tranches, then the consent only of the registered owners of a majority in aggregate principal amount of the outstanding Senior Debt Securities of all directly affected tranches, considered as one class, will be required. However, none of those amendments or modifications may:

(1)    change the dates on which the principal of or interest on a Senior Debt Security is due without the consent of the registered owner of that Senior Debt Security,

(2)    reduce any Senior Debt Security’s principal amount or rate of interest (or the amount of any installment of that interest) or change the method of calculating that rate without the consent of the registered owner of that Senior Debt Security,

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(3)    reduce any premium payable upon the redemption of a Senior Debt Security without the consent of the registered owner of that Senior Debt Security,

(4)    change the currency (or other property) in which a Senior Debt Security is payable without the consent of the registered owner of that Senior Debt Security,

(5)    impair the right to sue to enforce payments on any Senior Debt Security on or after the date that it states that the payment is due (or, in the case of redemption, on or after the redemption date) without the consent of the registered owner of that Senior Debt Security,

(6)    reduce the percentage in principal amount of the outstanding Senior Debt Securities of any series or tranche whose owners must consent to an amendment, supplement or waiver without the consent of the registered owner of each outstanding Senior Debt Security of that particular series or tranche,

(7)    reduce the requirements for quorum or voting of any series or tranche without the consent of the registered owner of each outstanding Senior Debt Security of that particular series or tranche, or

(8)    modify certain of the provisions of the Indenture relating to supplemental indentures, waivers of certain covenants and waivers of past defaults with respect to the Senior Debt Securities of any series or tranche, without the consent of the registered owner of each outstanding Senior Debt Security affected by the modification.

A supplemental indenture that changes or eliminates any provision of the Indenture that has expressly been included only for the benefit of one or more particular series or tranches of Senior Debt Securities, or that modifies the rights of the registered owners of Senior Debt Securities of that particular series or tranche with respect to that provision, will not affect the rights under the Indenture of the registered owners of the Senior Debt Securities of any other series or tranche. (Indenture, Section 1202).

The Indenture provides that, in order to determine whether the registered owners of the required principal amount of the outstanding Senior Debt Securities have given any request, demand, authorization, direction, notice, consent or waiver under the Indenture, or whether a quorum is present at the meeting of the registered owners of Senior Debt Securities, Senior Debt Securities owned by NEE Capital or any other obligor upon the Senior Debt Securities or any affiliate of NEE Capital or of that other obligor (unless NEE Capital, that affiliate or that obligor owns all Senior Debt Securities outstanding under the Indenture, determined without regard to this provision) will be disregarded and deemed not to be outstanding. (Indenture, Section 101).

If NEE Capital solicits any action under the Indenture from registered owners of Senior Debt Securities, NEE Capital may, at its option, fix in advance a record date for determining the registered owners of Senior Debt Securities entitled to take that action, but NEE Capital will not be obligated to do so. If NEE Capital fixes such a record date, that action may be taken before or after that record date, but only the registered owners of record at the close of business on that record date will be deemed to be registered owners of Senior Debt Securities for the purposes of determining whether registered owners of the required proportion of the outstanding Senior Debt Securities have authorized that action. For these purposes, the outstanding Senior Debt Securities will be computed as of the record date. Any action of a registered owner of any Senior Debt Security under the Indenture will bind every future registered owner of that Senior Debt Security, or any Senior Debt Security replacing that Senior Debt Security, with respect to anything that the indenture trustee or NEE Capital do, fail to do, or allow to be done in reliance on that action, whether or not that action is noted upon that Senior Debt Security. (Indenture, Section 104).

Resignation and Removal of Indenture Trustee.  The Indenture Trustee may resign at any time with respect to any series of Senior Debt Securities by giving written notice of its resignation to NEE Capital. Also, the registered owners of a majority in principal amount of the outstanding Senior Debt Securities of one or more series of Senior Debt Securities may remove the indenture trustee at any time with respect to the Senior Debt Securities of that series, by delivering an instrument evidencing this action to the indenture trustee and NEE Capital. The resignation or removal of the indenture trustee and the appointment of a successor trustee will not become effective until a successor trustee accepts its appointment.

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Except with respect to a trustee under the Indenture appointed by the registered owners of Senior Debt Securities, the indenture trustee will be deemed to have resigned and the successor will be deemed to have been appointed as trustee in accordance with the Indenture if:

(1)    no event of default under the Indenture or event that, after notice or lapse of time, or both, would become an event of default under the Indenture exists, and

(2)    NEE Capital has delivered to the indenture trustee a resolution of its Board of Directors appointing a successor trustee and that successor trustee has accepted that appointment in accordance with the terms of the Indenture. (Indenture, Section 910).

Notices.  Notices to registered owners of Senior Debt Securities will be sent by mail to the addresses of those registered owners as they appear in the security register for those Senior Debt Securities. (Indenture, Section 106).

Title.  NEE Capital, the indenture trustee, and any agent of NEE Capital or the indenture trustee, may treat the person in whose name a Senior Debt Security is registered as the absolute owner of that Senior Debt Security, whether or not that Senior Debt Security is overdue, for the purpose of making payments and for all other purposes, regardless of any notice to the contrary. (Indenture, Section 308).

Governing Law.  The Indenture and the Senior Debt Securities are governed by, and construed in accordance with, the laws of the State of New York, without regard to conflict of laws principles thereunder, except to the extent that the law of any other jurisdiction is mandatorily applicable. (Indenture, Section 112).

Book-Entry and Settlement

NEE Capital debentures which are released from the pledge following substitution of collateral or cash settlement of the purchase contracts will be issued in the form of one or more global certificates, which are referred to as global securities, registered in the name of the Depositary or its nominee. Except under the limited circumstances described below or except upon recreation of Corporate Units, NEE Capital debentures represented by the global securities will not be exchangeable for, and will not otherwise be issuable as, NEE Capital debentures in certificated form. The global securities described above may not be transferred except by the Depositary to a nominee of the Depositary or by a nominee of the Depositary to the Depositary or another nominee of the Depositary or to a successor depositary or its nominee.

Except as provided below, owners of beneficial interests in such a global security will not be entitled to receive physical delivery of NEE Capital debentures in certificated form and will not be considered the holders (as defined in the indenture) thereof for any purpose under the indenture, and no global security representing NEE Capital debentures shall be exchangeable, except for another global security of like denomination and tenor to be registered in the name of the Depositary or its nominee or a successor depositary or its nominee. Accordingly, each beneficial owner must rely on the procedures of the Depositary or if such person is not a participant, on the procedures of the participant through which such person owns its interest to exercise any rights of a holder under the indenture.

In the event that

•the Depositary notifies NEE Capital that it is unwilling or unable to continue as a Depositary for the global security certificates and no successor depositary has been appointed within 90 days after this notice,

•the Depositary at any time ceases to be a clearing agency registered under the Securities Exchange Act of 1934 at which time the Depositary is required to be so registered to act as the Depositary and no successor depositary has been appointed within 90 days after NEE Capital learns that the Depositary has ceased to be so registered, or

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•NEE Capital determines in its sole discretion that it will no longer have NEE Capital debentures represented by global securities or permit any the global security certificates to be exchangeable,

certificates for the NEE Capital debentures will be printed and delivered in exchange for beneficial interests in the global security certificates. Any global debenture certificate that is exchangeable pursuant to the preceding sentence shall be exchangeable for NEE Capital debenture certificates registered in the names directed by the Depositary. NEE Capital expects that these instructions will be based upon directions received by the Depositary from its participants with respect to ownership of beneficial interests in the global security certificates.

DESCRIPTION OF NEE GUARANTEE

General.  This section briefly summarizes some of the provisions of the Guarantee Agreement, dated as of June 1, 1999, between NEE and The Bank of New York Mellon, as guarantee trustee, referred to as the “Guarantee Trustee.” The Guarantee Agreement, referred to as the “Guarantee Agreement,” was executed for the benefit of the indenture trustee, which holds the Guarantee Agreement for the benefit of registered owners of the Senior Debt Securities covered by the Guarantee Agreement. This summary does not contain a complete description of the Guarantee Agreement. You should read this summary together with the Guarantee Agreement for a complete understanding of all the provisions. The Guarantee Agreement has previously been filed with the SEC and is an exhibit to the Form 10-K. In addition, the Guarantee Agreement is qualified as an indenture under the Trust Indenture Act of 1939 and is therefore subject to the provisions of the Trust Indenture Act of 1939. You should read the Trust Indenture Act of 1939 for a complete understanding of its provisions

Under the Guarantee Agreement, NEE absolutely, irrevocably and unconditionally guarantees the prompt and full payment, when due and payable (including upon acceleration or redemption), of the principal, interest and premium, if any, on the Senior Debt Securities that are covered by the Guarantee Agreement to the registered owners of those Senior Debt Securities, according to the terms of those Senior Debt Securities and the Indenture. Pursuant to the Guarantee Agreement, all of the Senior Debt Securities are covered by the Guarantee Agreement except Senior Debt Securities that by their terms are expressly not entitled to the benefit of the Guarantee Agreement. All of the NEE Capital debentures will be covered by the Guarantee Agreement. This guarantee is referred to as the “Guarantee.” NEE is only required to make these payments if NEE Capital fails to pay or provide for punctual payment of any of those amounts on or before the expiration of any applicable grace periods. (Guarantee Agreement, Section 5.01). In the Guarantee Agreement, NEE has waived its right to require the Guarantee Trustee, the indenture trustee or the registered owners of Senior Debt Securities covered by the Guarantee Agreement to exhaust their remedies against NEE Capital prior to bringing suit against NEE. (Guarantee Agreement, Section 5.06).

The Guarantee is a guarantee of payment when due (i.e., the guaranteed party may institute a legal proceeding directly against NEE to enforce its rights under the Guarantee Agreement without first instituting a legal proceeding against any other person or entity). The Guarantee is not a guarantee of collection. (Guarantee Agreement, Section 5.01).

The covenants in the Guarantee Agreement would not give registered owners of the Senior Debt Securities covered by the Guarantee Agreement protection in the event of a highly-leveraged transaction involving NEE.

Security and Ranking.  The Guarantee is an unsecured obligation of NEE and ranks equally and ratably with all other unsecured and unsubordinated indebtedness of NEE. There is no limit on the amount of other indebtedness, including guarantees, that NEE may incur or issue.

While NEE is a holding company that derives substantially all of its income from its operating subsidiaries, NEE’s subsidiaries are separate and distinct legal entities and have no obligation to make any payments under the Guarantee Agreement or to make any funds available for such payment. Therefore, the Guarantee effectively is subordinated to all indebtedness and other liabilities, including trade payables, debt and preferred stock, incurred or issued by NEE’s subsidiaries. In addition to trade liabilities, many of NEE’s operating subsidiaries incur debt in order to finance their business activities. All of this indebtedness will effectively be senior to the Guarantee.

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Neither the Indenture nor the Guarantee Agreement places any limit on the amount of liabilities, including debt or preferred stock, that NEE’s subsidiaries may issue, guarantee or incur.

Events of Default.  An event of default under the Guarantee Agreement will occur upon the failure of NEE to perform any of its payment obligations under the Guarantee Agreement. (Guarantee Agreement, Section 1.01). The registered owners of a majority of the aggregate principal amount of the outstanding Senior Debt Securities covered by the Guarantee Agreement have the right to:

(1)    direct the time, method and place of conducting any proceeding for any remedy available to the Guarantee Trustee under the Guarantee Agreement, or

(2)    direct the exercise of any trust or power conferred upon the Guarantee Trustee under the Guarantee Agreement. (Guarantee Agreement, Section 3.01).

The Guarantee Trustee must give notice of any event of default under the Guarantee Agreement known to the Guarantee Trustee to the registered owners of Senior Debt Securities covered by the Guarantee Agreement within 90 days after the occurrence of that event of default, in the manner and to the extent provided in subsection (c) of Section 313 of the Trust Indenture Act of 1939, unless such event of default has been cured or waived prior to the giving of such notice. (Guarantee Agreement, Section 2.07). The registered owners of all outstanding Senior Debt Securities may waive any past event of default and its consequences. (Guarantee Agreement, Section 2.06).

The Guarantee Trustee, the indenture trustee and the registered owners of Senior Debt Securities covered by the Guarantee Agreement have all of the rights and remedies available under applicable law and may sue to enforce the terms of the Guarantee Agreement and to recover damages for the breach of the Guarantee Agreement. The remedies of each of the Guarantee Trustee, the indenture trustee and the registered owners of Senior Debt Securities covered by the Guarantee Agreement, to the extent permitted by law, are cumulative and in addition to any other remedy now or hereafter existing at law or in equity. At the option of any of the Guarantee Trustee, the indenture trustee or the registered owners of Senior Debt Securities covered by the Guarantee Agreement, that person or entity may join NEE in any lawsuit commenced by that person or entity against NEE Capital with respect to any obligations under the Guarantee Agreement. Also, that person or entity may recover against NEE in that lawsuit, or in any independent lawsuit against NEE, without first asserting, prosecuting or exhausting any remedy or claim against NEE Capital. (Guarantee Agreement, Section 5.06).

NEE is required to deliver to the Guarantee Trustee an annual statement as to its compliance with all conditions under the Guarantee Agreement. (Guarantee Agreement, Section 2.04).

Modification.  NEE and the Guarantee Trustee may, without the consent of any registered owner of Senior Debt Securities covered by the Guarantee Agreement, agree to any changes to the Guarantee Agreement that do not materially adversely affect the rights of registered owners. The Guarantee Agreement also may be amended with the prior approval of the registered owners of a majority in aggregate principal amount of all outstanding Senior Debt Securities covered by the Guarantee Agreement. However, the right of any registered owner of Senior Debt Securities covered by the Guarantee Agreement to receive payment under the Guarantee Agreement on the due date of the Senior Debt Securities held by that registered owner, or to institute suit for the enforcement of that payment on or after that due date, may not be impaired or affected without the consent of that registered owner. (Guarantee Agreement, Section 6.01).

Termination of the Guarantee Agreement.  The Guarantee Agreement will terminate and be of no further force and effect upon full payment of all Senior Debt Securities covered by the Guarantee Agreement. (Guarantee Agreement, Section 5.05).

Governing Law.  The Guarantee Agreement is governed by and will be construed in accordance with the laws of the State of New York, without regard to conflict of laws principles thereunder, except to the extent that the law of any other jurisdiction is mandatorily applicable. (Guarantee Agreement, Section 5.07).

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UNITED STATES FEDERAL INCOME TAX DISCUSSION

Unless otherwise stated, this discussion deals only with Equity Units, applicable ownership interests in NEE Capital debentures (or the Treasury portfolio, or Treasury securities) and NEE common stock held as capital assets (generally, assets held for investment) by holders that are U.S. persons (as defined below) that purchased Equity Units upon original issuance at their “issue price,” which equals the first price to the public at which a substantial amount of the Equity Units were sold for money (not including sales to bond houses, brokers or similar persons or organizations acting in the capacity of underwriters, placement agents or wholesalers). The tax treatment of a holder may vary depending on the holder’s particular situation. This discussion does not address all of the tax consequences that may be relevant to holders that may be subject to special tax treatment such as, for example, banks, insurance companies, broker dealers, tax exempt organizations, foreign taxpayers, regulated investment companies, real estate investment trusts, controlled foreign corporations, passive foreign investment companies, persons subject to special tax accounting rules as a result of their use of applicable financial statements, persons holding Equity Units, applicable ownership interests in NEE Capital debentures (or the Treasury portfolio, or Treasury securities), or shares of NEE common stock as part of a straddle, hedge, conversion transaction or other integrated investment and persons whose functional currency is not the U.S. dollar. This discussion does not address any aspects of state, local, or foreign tax laws. In addition, this discussion does not address all of the U.S. federal income tax considerations that may be relevant to holders, such as the Medicare contribution tax or U.S. federal tax laws other than those pertaining to income tax (such as the estate or gift tax), and the effect of those taxes on the ownership and disposition of the Equity Units, applicable ownership interests in NEE Capital debentures (or the Treasury portfolio, or Treasury securities) or NEE common stock acquired under a purchase contract. This discussion is based on the U.S. federal income tax laws, regulations, rulings and decisions in effect as of the date hereof, which are subject to change or differing interpretations, possibly on a retroactive basis. Holders should consult their own tax advisors as to the particular tax consequences to them of purchasing, owning, and disposing of the Equity Units, applicable ownership interests in NEE Capital debentures (or the Treasury portfolio, or Treasury securities) or NEE common stock acquired under a purchase contract, including the application and effect of U.S. federal, state, local and foreign tax laws.

For purposes of this discussion, the term “U.S. person” means:

•an individual who is a citizen or resident of the United States;

•a corporation (or any other entity treated as a corporation for U.S. federal income tax purposes) created or organized in or under the laws of the United States or any state thereof or the District of Columbia;

•an estate the income of which is subject to U.S. federal income taxation regardless of its source; or

•a trust if  (a) a court within the United States is able to exercise primary supervision over the administration of the trust and one or more U.S. persons have the authority to control all substantial decisions of the trust or (b) the trust has in effect a valid election to be treated as a domestic trust for U.S. federal income tax purposes.

A “non-U.S. holder” is a holder that is an individual, corporation, estate or trust that is not a U.S. person.

If a partnership (or any other entity or arrangement treated as a partnership for U.S. federal income tax purposes) holds Equity Units, any component thereof including applicable ownership interests in NEE Capital debentures (or the Treasury portfolio, or Treasury securities), or any NEE common stock acquired under a purchase contract, the U.S. federal income tax treatment of a partner will generally depend upon the status of the partner and upon the activities of the partnership. Partners of partnerships holding any of the above instruments should consult their tax advisors.

The IRS has issued a ruling, Rev. Rul. 2003-97, 2003-2 C.B. 380, addressing certain aspects of instruments substantially similar to the Equity Units. In the ruling, the IRS concluded that the notes issued as part of a unit with a purchase contract were debt for U.S. federal income tax purposes. Pursuant to this ruling, NEE Capital reports the NEE Capital debentures issued as part of an Equity Unit with a purchase contract as indebtedness for U.S. federal

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income tax purposes. The remainder of this discussion assumes that the NEE Capital debentures will be respected as indebtedness for U.S. federal income tax purposes.

Holders should consult their own tax advisors with respect to the tax consequences to them of purchasing, owning and disposing of the Equity Units, or any component thereof including applicable ownership interests in NEE Capital debentures (or the Treasury portfolio, or Treasury securities), and any NEE common stock acquired under a purchase contract, including the tax consequences under state, local, foreign and other tax laws and the possible effects of changes in the U.S. federal or other tax laws.

U.S. Holders

Allocation of Original Purchase Price

Each Equity Unit is treated as an investment unit consisting of two components, an applicable ownership interest in a NEE Capital debenture (or the Treasury portfolio, or Treasury securities) and a related purchase contract. For purpose of the original issue discount rules and initial tax basis calculations, the allocation of original issue purchase price between these components is determined based on the respective fair market values of these components at the time the Equity Units are originally issued for federal income tax purposes. NEE Capital reports the Equity Unit original issue date fair market value of the applicable ownership interest in the NEE Capital debenture as the NEE Capital Debenture Fair Market Value and Equity Unit original issue date fair market value of each purchase contract as $0. This position is binding upon holders (but not on the IRS) unless holders explicitly disclose a contrary position on a statement attached to their timely filed U.S. federal income tax returns for the taxable year in which an Equity Unit is first issued. Thus, absent such disclosure, holders should allocate the original issue purchase price for an Equity Unit for purposes of the original issue discount rules and initial tax basis calculations in accordance with the foregoing. The remainder of this discussion assumes that this allocation will be respected for U.S. federal income tax purposes.

Ownership of Applicable Interests in the NEE Capital Debentures or Treasury Securities

Holders are treated as owning the applicable interests in NEE Capital debentures or Treasury securities constituting a part of the Corporate Units or Treasury Units, respectively, for U.S. federal income tax purposes. NEE, NEE Capital and, by virtue of their acquisition of Equity Units, holders agree to treat the applicable interests in the NEE Capital debentures or Treasury securities constituting a part of the Equity Units as owned by holders for U.S. federal income tax purposes, and the remainder of this discussion assumes such treatment. The U.S. federal income tax consequences of owning the applicable interests in the NEE Capital debentures or Treasury securities are discussed below (see “— NEE Capital Debentures,” “— Treasury Securities” and “— Remarketing, Special Event Redemption and Mandatory Redemption of NEE Capital Debentures”).

Sales, Exchanges or Other Taxable Dispositions of Equity Units

If holders sell, exchange or otherwise dispose of an Equity Unit in a taxable disposition (a “disposition”), they will be treated as having sold, exchanged or disposed of each of the purchase contract and the applicable ownership interest in the NEE Capital debenture, or the applicable ownership interest in the Treasury portfolio or the Treasury securities, as the case may be, that constitute such Equity Unit, and the proceeds realized on such disposition will be allocated among the components of the Equity Unit in proportion to the respective fair market values of the components. As a result, a holder generally will recognize gain or loss equal to the difference between the portion of the proceeds received that is allocable to the component and the holder’s adjusted tax basis in the applicable component, except to the extent the holder is treated as receiving an amount with respect to accrued interest, accrued contract adjustment payments or deferred contract adjustment payments on the purchase contract, which amount may be treated as ordinary income to the extent not previously included in income. In the case of the purchase contract, or the applicable ownership interest in the Treasury portfolio and Treasury securities, such gain or loss will generally be capital gain or loss, and such gain or loss generally will be long-term capital gain or loss if holders held the particular component for more than one year immediately prior to such disposition. Under U.S. federal income tax law, certain non-corporate holders, including individuals, are eligible for preferential tax rates with respect to long-term capital gains. The deductibility of capital losses is subject to certain limitations. The rules governing the determination of the character of gain or loss on the disposition of applicable ownership interests in

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NEE Capital debentures are summarized under “—NEE Capital Debentures—Sales, Exchanges or Other Taxable Dispositions of Applicable Ownership Interests in NEE Capital Debentures.”

If the disposition of an Equity Unit occurs when the purchase contract has a negative value, holders are considered to have received additional consideration for the applicable ownership interest in the NEE Capital debenture, or the applicable ownership interest in the Treasury portfolio or Treasury securities, as the case may be, in an amount equal to such negative value and to have paid such amount to be released from their obligation under the purchase contract. Because, as discussed below, any gain on the disposition of applicable ownership interests in NEE Capital debentures prior to the earlier of the reset effective date and the Purchase Contract Settlement Date (the “Reset Date”) generally will be treated as ordinary interest income for U.S. federal income tax purposes, the ability to offset such interest income with a loss on the purchase contract may be limited. Holders should consult their tax advisors regarding a disposition of an Equity Unit at a time when the purchase contract has a negative value.

In determining gain or loss, contract adjustment payments or deferred contract adjustment payments that have been received by holders, but have not previously been included in their income, should either reduce their adjusted tax basis in the purchase contract or result in an increase in the amount realized on the disposition of the purchase contract. Any contract adjustment payments or deferred contract adjustment payments previously included in holders’ income but not received by the holders should increase their adjusted tax basis in the purchase contract (see “—Purchase Contracts—Contract Adjustment Payments and Deferred Contract Adjustment Payments” below).

NEE Capital Debentures

The discussion in this section will apply to holders if they hold applicable ownership interests in NEE Capital debentures or Corporate Units that include applicable ownership interests in NEE Capital debentures.

Original Issue Discount. Because of the manner in which the interest rate on the NEE Capital debentures is to be reset, the NEE Capital debentures are classified as contingent payment debt instruments subject to the “noncontingent bond method” for accruing OID, as set forth in the applicable Treasury Regulations. NEE Capital intends to treat the NEE Capital debentures in that manner, and the remainder of this discussion assumes that the NEE Capital debentures will be so treated for U.S. federal income tax purposes. As discussed more fully below, the effects of applying such method will be:

•to require holders, regardless of their usual method of tax accounting, to use an accrual method with respect to the interest income on their applicable ownership interests in NEE Capital debentures;

•for all accrual periods until the Reset Date, and possibly for accrual periods thereafter with respect to applicable ownership interests in NEE Capital debentures, to require holders to accrue interest income in excess of interest payments actually received; and

•generally to result in ordinary, rather than capital, treatment of any gain or loss on the sale, exchange or other disposition of applicable ownership interests in NEE Capital debentures.

See “—Sales, Exchanges or Other Taxable Dispositions of Applicable Ownership Interests in NEE Capital Debentures.”

Holders are required to accrue OID on a constant yield to maturity basis based on the “comparable yield” of the NEE Capital debentures. The comparable yield of the NEE Capital debentures is generally the rate at which NEE Capital would issue a fixed rate debt instrument with terms and conditions similar to the NEE Capital debentures (which rate will exceed the current interest payments on the NEE Capital debentures). NEE Capital has determined that, for the NEE Capital debentures,

•(with respect to the 4.872% Corporate Units) the comparable yield is 2.25% and the projected payments, per $50 applicable ownership interest of NEE Capital debentures, are $0.2332 on the Initial Payment Date, $0.2625 for each subsequent quarter ending on or prior to the Purchase Contract Settlement Date and $0.2852 for each semi-annual period ending after the Purchase Contract

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Settlement Date. NEE Capital has also determined (with respect to the 4.872% Corporate Units) that the projected payment for the NEE Capital debentures, per $50 applicable ownership interest of NEE Capital debentures, at the maturity date is $50.2852 (which includes the stated principal amount of the NEE Capital debentures as well as the final projected interest payment);

•(with respect to the 5.279% Corporate Units) the comparable yield is 2.00% and the projected payments, per $50 applicable ownership interest of NEE Capital debentures, are $0.2556 on the Initial Payment Date, $0.23 for each subsequent quarter ending on or prior to the Purchase Contract Settlement Date and $0.2143 for each semi-annual period ending after the Purchase Contract Settlement Date. NEE Capital has also determined (with respect to the 5.279% Corporate Units) that the projected payment for the NEE Capital debentures, per $50 applicable ownership interest of NEE Capital debentures, at the maturity date is $50.2143 (which includes the stated principal amount of the NEE Capital debentures as well as the final projected interest payment); and

•(with respect to the 6.219% Corporate Units) the comparable yield is 0.89% and the projected payments, per $50 applicable ownership interest of NEE Capital debentures, are $0.0516 on the Initial Payment Date, $0.0636 for each subsequent quarter ending on or prior to the Purchase Contract Settlement Date and $0.00 for each semi-annual period ending after the Purchase Contract Settlement Date. NEE Capital has also determined (with respect to the 6.219% Corporate Units) that the projected payment for the NEE Capital debentures, per $50 applicable ownership interest of NEE Capital debentures, at the maturity date is $50.00 (which includes the stated principal amount of the NEE Capital debentures as well as the final projected interest payment).

The amount of OID on a NEE Capital debenture for each accrual period is determined by multiplying the comparable yield of the NEE Capital debenture (adjusted for the length of the accrual period) by the NEE Capital debenture’s adjusted issue price at the beginning of the accrual period. Based on the allocation of the purchase price of each Corporate Unit described above, the adjusted issue price of each applicable ownership interest in a NEE Capital debenture, per $50 applicable ownership interest of NEE Capital debentures, at the beginning of the first accrual period will be the NEE Capital Debenture Fair Market Value, and the adjusted issue price of each applicable ownership interest in a NEE Capital debenture at the beginning of each subsequent accrual period will be equal to the NEE Capital Debenture Fair Market Value, increased by any OID previously accrued by holders on such applicable ownership interest in the NEE Capital debenture and decreased by the amount of projected payments on such applicable ownership interest in the NEE Capital debenture through such date. The amount of OID so determined will then be allocated on a ratable basis to each day in the accrual period that holders hold such applicable ownership interest in the NEE Capital debenture.

If, after the Reset Date, the remaining amounts of principal and interest payable on an applicable ownership interest in NEE Capital debentures differ from the payments set forth on the applicable projected payment schedule, negative or positive adjustments reflecting such difference are generally taken into account by holders as adjustments to interest income in a reasonable manner over the period to which they relate.

A holder is generally bound by the comparable yield and projected payment schedules for applicable ownership interests in NEE Capital debentures provided by NEE Capital unless either is unreasonable. If a holder decides to use its own comparable yield and projected payment schedules, the holder must explicitly disclose this fact and the reason for using different comparable yield and projected payment schedules. In general, this disclosure must be made on a statement attached to the holder’s timely filed U.S. federal income tax return for the taxable year that includes the date of the holder’s acquisition of the applicable ownership interests in NEE Capital debentures.

The foregoing comparable yield and projected payment schedules are supplied by NEE Capital solely for computing income under the noncontingent bond method for U.S. federal income tax purposes and do not constitute projections or representations as to the amounts that holders will actually receive as a result of owning applicable ownership interests in NEE Capital debentures or Corporate Units.

Adjustment to Tax Basis in Applicable Ownership Interests in NEE Capital Debentures. A holder’s tax basis in an applicable ownership interest in NEE Capital debentures will be increased by the amount of OID

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included in income with respect to such applicable ownership interest in NEE Capital debentures and decreased by the amount of projected payments with respect to such applicable ownership interest in NEE Capital debentures through the computation date.

Sales, Exchanges or Other Taxable Dispositions of Applicable Ownership Interests in NEE Capital Debentures. Holders will recognize gain or loss on a disposition of an applicable ownership interest in NEE Capital debentures (including a redemption for cash or the remarketing thereof) in an amount equal to the difference between the amount realized by holders on the disposition of the applicable ownership interest in NEE Capital debentures and their adjusted tax basis in the applicable ownership interest in NEE Capital debentures. Selling expenses incurred by holders, including the remarketing fee, will reduce the amount of gain or increase the amount of loss recognized by holders upon a disposition of applicable ownership interests in NEE Capital debentures. Gain recognized on the disposition of applicable ownership interests in NEE Capital debentures prior to the Reset Date will be treated as ordinary interest income. Loss recognized on the disposition of applicable ownership interests in NEE Capital debentures prior to the Reset Date will be treated as ordinary loss to the extent of the holders’ prior inclusions of OID on the applicable ownership interests in NEE Capital debentures. Any loss in excess of such amount will be treated as a capital loss. In general, gain recognized on the disposition of applicable ownership interests in NEE Capital debentures on or after the Reset Date will be ordinary interest income to the extent attributable to the remaining positive adjustments, if any, not already taken into account as positive adjustments to interest income under a reasonable manner as described above under “— Original Issue Discount.” Any gain recognized in excess of such amount and any loss recognized on such a disposition will generally be treated as a capital gain or loss. Under U.S. federal income tax law, certain non-corporate holders, including individuals, are eligible for preferential tax rates in respect of long-term capital gains. The deductibility of capital losses is subject to certain limitations.

Treasury Securities

The discussion in this section will apply to holders that hold Treasury Units or Treasury securities.

Original Issue Discount. If holders hold Treasury Units, they will be required to treat their ownership interest in the Treasury securities included in a Treasury Unit as an interest in a bond that was originally issued on the date they acquired the Treasury securities. Any such Treasury securities that are owned or treated as owned by holders will have OID equal to the excess of the amount payable at maturity of such Treasury securities over the purchase price thereof. Holders are required to include such OID in income on a constant yield to maturity basis over the period between the purchase date of the Treasury securities and the maturity date of the Treasury securities, regardless of their regular method of tax accounting and in advance of the receipt of cash attributable to such OID. A holder’s adjusted tax basis in the Treasury securities will be increased by the amounts of such OID included in such holder’s gross income.

Sales, Exchanges or Other Taxable Dispositions of Treasury Securities. As discussed below, in the event that holders obtain the release of Treasury securities by delivering applicable ownership interests in NEE Capital debentures to the collateral agent, holders generally will not recognize gain or loss upon such substitution. Holders will recognize gain or loss on a subsequent disposition of the Treasury securities in an amount equal to the difference between the amount realized by holders on such disposition and their adjusted tax basis in the Treasury securities. Such gain or loss generally will be capital gain or loss and generally will be long-term capital gain or loss if holders held such Treasury securities for more than one year immediately prior to such disposition. Under U.S. federal income tax law, certain non-corporate holders, including individuals, are eligible for preferential tax rates in respect of long-term capital gains. The deductibility of capital losses is subject to certain limitations.

Purchase Contracts

Contract Adjustment Payments and Deferred Contract Adjustment Payments. There is no direct authority addressing the treatment, under current law, of the contract adjustment payments or deferred contract adjustment payments, and such treatment is, therefore, unclear. Contract adjustment payments and deferred contract adjustment payments may constitute taxable ordinary income to holders when received or accrued, in accordance with their regular method of tax accounting. To the extent NEE is required to file information returns with respect to contract adjustment payments or deferred contract adjustment payments, it intends to report such payments as taxable

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ordinary income to holders. Holders should consult their tax advisors concerning the treatment of contract adjustment payments and deferred contract adjustment payments.

The treatment of contract adjustment payments and deferred contract adjustment payments could affect a holder’s adjusted tax basis in a purchase contract or NEE common stock received under a purchase contract or the amount realized by a holder upon the sale or disposition of an Equity Unit or the termination of a purchase contract. In particular, any contract adjustment payments or deferred contract adjustment payments that have been:

•included in holders’ income, but not paid to them, should increase their adjusted tax basis in the purchase contract; and

•paid to holders, but not included in their income, should either reduce their adjusted tax basis in the purchase contract or result in an increase in the amount realized on the disposition of the purchase contract.

See “— Acquisition of NEE Common Stock Under a Purchase Contract,” “— Sales, Exchanges or Other Taxable Dispositions of Equity Units” and “— Termination of Purchase Contract.”

Acquisition of NEE Common Stock Under a Purchase Contract. Holders generally will not recognize gain or loss on the purchase of NEE common stock under a purchase contract, including upon early settlement upon a fundamental change or any other early settlement, except with respect to any cash paid in lieu of a fractional share of NEE common stock. Holders’ aggregate initial tax basis in NEE common stock received under a purchase contract will generally equal the purchase price paid for such common stock, plus the properly allocable portion of their adjusted tax basis (if any) in the purchase contract, less the portion of such purchase price and adjusted tax basis allocable to the fractional share. The holding period for NEE common stock received under a purchase contract will commence on the day following the acquisition of such common stock.

Ownership of NEE Common Stock Acquired Under the Purchase Contract. Any distribution on NEE common stock paid by NEE out of its current or accumulated earnings and profits (as determined for U.S. federal income tax purposes) will constitute a dividend and will be includible in income by holders when received. Any such dividend will be eligible for the dividends received deduction if the holder is an otherwise qualifying corporate holder that meets the holding period and other requirements for the dividends received deduction. Under U.S. federal income tax law, individuals who receive dividends are eligible for a reduced rate of taxation if certain holding period and other requirements are satisfied.

Upon a disposition of NEE common stock, holders generally will recognize capital gain or loss equal to the difference between the amount realized and their adjusted tax basis in NEE common stock. Such capital gain or loss generally will be long-term capital gain or loss if they held such common stock for more than one year immediately prior to such disposition. Under U.S. federal income tax law, certain non-corporate holders, including individuals, are eligible for preferential tax rates in respect of long-term capital gains. The deductibility of capital losses is subject to certain limitations.

Early Settlement of Purchase Contract. Holders will not recognize gain or loss on the receipt of their proportionate share of applicable interests in NEE Capital debentures or Treasury securities or the applicable ownership interest in a Treasury portfolio upon early settlement of a purchase contract, and holders will have the same adjusted tax basis in such applicable interests in NEE Capital debentures, Treasury securities or the applicable ownership interest in a Treasury portfolio as before such early settlement.

Termination of Purchase Contract. If a purchase contract terminates, holders will recognize gain or loss equal to the difference between the amount realized (if any) upon such termination and their adjusted tax basis (if any) in the purchase contract at the time of such termination. Such gain or loss generally will be capital gain or loss and generally will be long-term capital gain or loss if holders held such purchase contract for more than one year immediately prior to such termination. Under U.S. federal income tax law, certain non-corporate holders, including individuals, are eligible for preferential tax rates in respect of long-term capital gains. The deductibility of capital losses is subject to certain limitations. A holder will not recognize gain or loss on the receipt of the holder’s

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proportionate share of applicable ownership interests in NEE Capital debentures or Treasury securities or the applicable ownership interest in a Treasury portfolio upon termination of the purchase contract and will have the same adjusted tax basis in the applicable ownership interests in NEE Capital debentures, Treasury securities or the applicable ownership interest in a Treasury portfolio as before such distribution.

Adjustment to Settlement Rate. A holder might be treated as receiving a constructive distribution from NEE if  (1) the settlement rate is adjusted (or fails to be adjusted) and as a result of that adjustment (or failure to adjust) such holder’s proportionate interest in NEE’s assets or earnings and profits is increased and (2) the adjustment (or failure to adjust) is not made pursuant to a bona fide, reasonable anti-dilution formula. An adjustment in the settlement rate would not be considered made pursuant to such a formula if the adjustment were made to compensate a holder for certain taxable distributions with respect to NEE common stock. Thus, under certain circumstances, an adjustment to (or a failure to adjust) the settlement rate might give rise to a taxable dividend to a holder even though such holder would not receive any distribution related thereto.

Substitution of Treasury Securities to Create or Recreate Treasury Units

Holders of Corporate Units that deliver Treasury securities to the collateral agent in substitution for applicable ownership interests in the NEE Capital debentures or the applicable ownership interest in a Treasury portfolio will not recognize gain or loss upon their delivery of such Treasury securities or their receipt of the applicable ownership interest in NEE Capital debentures or the applicable ownership interest in a Treasury portfolio. Holders will continue to take into account items of income or deduction otherwise includible or deductible, respectively, by holders with respect to such Treasury securities and such applicable ownership interests in NEE Capital debentures or the applicable ownership interest in a Treasury portfolio, and their adjusted tax bases in the Treasury securities, the applicable ownership interests in NEE Capital debentures or the applicable ownership interest in a Treasury portfolio and the purchase contract will not be affected by such delivery and release.

Substitution of Applicable Ownership Interests in NEE Capital Debentures or the Applicable Ownership Interest in a Treasury Portfolio to Recreate Corporate Units

Holders of Treasury Units that deliver applicable ownership interests in NEE Capital debentures or the applicable ownership interest in a Treasury portfolio to the collateral agent in substitution for Treasury securities to recreate Corporate Units will not recognize gain or loss upon their delivery of such applicable ownership interests in NEE Capital debentures or the applicable ownership interest in a Treasury portfolio or their receipt of the Treasury securities. Holders will continue to take into account items of income or deduction otherwise includible or deductible, respectively, by holders with respect to such Treasury securities and applicable ownership interests in NEE Capital debentures or the applicable ownership interest in a Treasury portfolio, and their adjusted tax bases in the Treasury securities, applicable ownership interests in the NEE Capital debentures or the applicable ownership interest in a Treasury portfolio and the purchase contract will not be affected by such delivery and release.

Remarketing, Special Event Redemption and Mandatory Redemption of NEE Capital Debentures

A remarketing, a special event redemption or a mandatory redemption will be a taxable event for holders of applicable ownership interests in NEE Capital debentures, which will be subject to tax in the manner described above under “— NEE Capital Debentures — Sales, Exchanges or Other Taxable Dispositions of Applicable Ownership Interests in NEE Capital Debentures.”

Ownership of Treasury Portfolio. In the event of a successful remarketing of the NEE Capital debentures, a special event redemption prior to the Purchase Contract Settlement Date or a mandatory redemption prior to the Purchase Contract Settlement Date (if the purchase contracts have not been so previously or concurrently terminated), NEE Capital and, by virtue of their acquisition of Corporate Units, holders agree to treat the applicable ownership interest in the Treasury portfolio constituting a part of their Corporate Units as owned by holders for U.S. federal income tax purposes. In such a case, holders will be required to include in income any amount earned on such pro rata portion of the Treasury portfolio for U.S. federal income tax purposes. The remainder of this discussion assumes that holders of Corporate Units will be treated as the owners of the applicable ownership interest in the Treasury portfolio constituting a part of such Corporate Units for U.S. federal income tax purposes.

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Interest Income and Original Issue Discount. The Treasury portfolio will consist of U.S. Treasury securities (or principal or interest strips thereof). Following a successful remarketing of the NEE Capital debentures, a special event redemption prior to the Purchase Contract Settlement Date or a mandatory redemption prior to the Purchase Contract Settlement Date, holders will be required to treat their pro rata portion of each U.S. Treasury security in the Treasury portfolio as a bond that was originally issued on the date the collateral agent acquired the relevant U.S. Treasury securities and that has OID equal to their pro rata portion of the excess of the amounts payable on such U.S. Treasury securities over the value of the U.S. Treasury securities at the time the collateral agent acquires them on behalf of holders of Corporate Units. Holders will be required to include such OID (other than OID on short-term U.S. Treasury securities (as defined below)) in income for U.S. federal income tax purposes as it accrues on a constant yield to maturity basis, regardless of their regular method of tax accounting. To the extent that a payment from the Treasury portfolio made in respect of a scheduled interest payment on remarketed or redeemed applicable ownership interests in NEE Capital debentures exceeds the amount of such OID, such payment will be treated as a return of a holder’s investment in the Treasury portfolio and will not be considered current income for U.S. federal income tax purposes.

In the case of any U.S. Treasury security with a maturity of one year or less from the date of its issue (a “short-term U.S. Treasury Security”), holders will generally be required to include OID in income as it accrues only if they are accrual basis taxpayers. If holders are accrual basis taxpayers, they will generally accrue such OID on a straight line basis, unless they make an election to accrue such OID on a constant yield to maturity basis.

Tax Basis of the Applicable Ownership Interest in a Treasury Portfolio. The initial tax basis of holders in their applicable ownership interest in a Treasury portfolio will equal their pro rata portion of the amount paid by the collateral agent for the Treasury portfolio. A holder’s adjusted tax basis in the applicable ownership interest in the Treasury portfolio will be increased by the amount of OID included in income with respect thereto and decreased by the amount of cash received in respect of the Treasury portfolio.

Sales, Exchanges or Other Dispositions of the Applicable Ownership Interest in a Treasury Portfolio. Holders that obtain the release of their applicable ownership interest in a Treasury portfolio and subsequently dispose of such interest will recognize gain or loss on such disposition in an amount equal to the difference between the amount realized upon such disposition and such holders’ adjusted tax basis in the applicable ownership interest in that Treasury portfolio. Such gain or loss generally will be capital gain or loss and generally will be long-term capital gain or loss if holders held such applicable interest in the Treasury portfolio for more than one year immediately prior to such disposition. Under U.S. federal income tax law, certain non-corporate holders, including individuals, are eligible for preferential tax rates in respect of long-term capital gains. The deductibility of capital losses is subject to certain limitations.

Backup Withholding Tax and Information Reporting

Unless holders are exempt recipients, such as corporations, interest, OID, contract adjustment payments or deferred contract adjustment payments, and dividends received on, and proceeds received from the sale of, Equity Units, applicable ownership interests in NEE Capital debentures, purchase contracts, Treasury securities, the applicable ownership interest in a Treasury portfolio, or NEE common stock acquired under a purchase contract, as the case may be, may be subject to information reporting and may also be subject to U.S. federal backup withholding tax if holders fail to supply accurate taxpayer identification numbers or otherwise fail to comply with applicable U.S. information reporting or certification requirements.

The amount of any backup withholding from a payment to a holder will be allowed as a credit against the holder’s U.S. federal income tax liability and may entitle the holder to a refund, provided that the required information is timely and properly furnished to the IRS.

Additional Disclosure Requirements

If a holder sells Equity Units, applicable ownership interests in the NEE Capital debentures, the applicable ownership interest in the Treasury portfolio, Treasury securities, or NEE common stock at a loss that meets certain thresholds, the holder (and/or the partners or shareholders of the holder, if the holder is a partnership or an S corporation for U.S. federal income tax purposes) may be required to file a disclosure statement with the IRS.

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Holders and their partners or shareholders should consult their own tax advisors with respect to any disclosure requirements that may apply to them in their own particular circumstances.

Non-U.S. Holders

The following discussion applies to “non-U.S. holders” as defined above. This discussion does not address all aspects of U.S. federal income tax law that may be relevant to non-U.S. holders in light of their particular circumstances, such as non-U.S. holders that are subject to special tax treatment (for example, persons engaged in a trade or business in the United States, controlled foreign corporations, or passive foreign investment companies), nor does it address alternative minimum taxes, estate taxes or state, local, or foreign taxes. In addition, this discussion does not address the U.S. tax consequences to any non-U.S. holder that owns 10% or more of the Equity Units or that owns or is deemed to own, for purposes of Section 871(h) of the Code, 10% or more of the total combined voting power of all classes of NEE’s stock entitled to vote. Prospective investors that are subject to special tax treatment, and investors that own 10% or more of the Equity Units, or own or are deemed to own, for purposes of Section 871(h)(3) of the Code, 10% or more of the total combined voting power of all classes of NEE’s stock entitled to vote, are urged to consult their own tax advisors with respect to the U.S. federal income tax consequences to them of an investment in the Equity Units, in light of their own particular circumstances.

Payments of Principal and Interest on Applicable Ownership Interests in NEE Capital Debentures, Treasury Securities, and the Applicable Ownership Interest in the Treasury Portfolio

Except as provided below under “— Backup Withholding and Information Reporting” and “— Additional Withholding Requirements,” no U.S. withholding tax will be imposed on any payment of interest (including any OID) on applicable ownership interests in NEE Capital debentures, Treasury securities or the applicable ownership interest in the Treasury portfolio, under the “portfolio interest rule” provided that (1) interest paid is not effectively connected with the non-U.S. holder’s conduct of a trade or business in the U.S., (2) the non-U.S. holder is not a controlled foreign corporation related to NEE through stock ownership, (3) the non-U.S. holder is not a bank whose receipt of interest is described in Section 881(c)(3)(A) of the Code, (4) in the case of applicable ownership interests in NEE Capital debentures, the non-U.S. holder does not own, either directly or through the application of certain constructive ownership rules, 10% or more of the total combined voting power of all classes of NEE’s voting stock for U.S. federal income tax purposes, and (5) (a) the non-U.S. holder provides a properly executed IRS Form W-8BEN or W-8BEN-E (or suitable substitute form) and the payor does not have actual knowledge or reason to know that the non-U.S. holder is a U.S. person, or (b) if the non-U.S. holder is a foreign partnership or holds the Equity Units, applicable ownership interests in NEE Capital debentures, Treasury securities, or the applicable ownership in a Treasury portfolio through certain foreign intermediaries, certain alternative certification requirements are satisfied.

If a non-U.S. holder cannot satisfy the requirements described above for the “portfolio interest rule”, payments of interest (including OID) made to such non-U.S. holder will be subject to a 30% U.S. federal withholding tax, unless the non-U.S. holder provides the applicable withholding agent with a properly executed IRS Form W-8BEN or W-8BEN-E (or suitable substitute form) claiming an exemption from, or reduction in the rate of, withholding under the benefit of an applicable tax treaty; or IRS Form W-8ECI (or suitable substitute form) stating that interest paid on applicable ownership interests in NEE Capital debentures, Treasury securities or the applicable ownership interest in the Treasury portfolio is not subject to withholding tax because it is effectively connected with the non-U.S. holder’s conduct of a trade or business in the U.S.

The 30% U.S. federal withholding tax generally will not apply to any payment of principal on applicable ownership interests in NEE Capital debentures, Treasury securities or the applicable ownership interest in the Treasury portfolio.

Dividends

Dividends received by a non-U.S. holder on NEE common stock generally will be subject to U.S. withholding tax at a 30% rate. In certain circumstances, a non-U.S. holder may be entitled to a reduced rate of withholding pursuant to an applicable income tax treaty. In order to claim the benefits of an applicable income tax

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treaty, a non-U.S. holder will be required to provide a properly executed IRS Form W-8BEN or W-8BEN-E (or suitable substitute form).

As discussed above, an adjustment to the settlement rate may result in a constructive distribution that is treated as a taxable constructive dividend to the holder of Equity Units. See “U.S. Holders — Purchase Contracts — Adjustment to Settlement Rate.” If NEE determines that any such adjustment results in a constructive dividend to a non-U.S. holder of Equity Units, NEE may withhold on interest (or some other amount) paid to a non-U.S. holder in order to pay the proper U.S. withholding tax on such constructive dividend.

Contract Adjustment Payments

NEE intends to treat any contract adjustment payments paid to a non-U.S. holder as amounts generally subject to U.S. withholding tax at a 30% rate. In certain circumstances, a non-U.S. holder may be entitled to a reduced rate of withholding (or a complete exemption from withholding) pursuant to an applicable income tax treaty. In order to claim any benefits of an applicable income tax treaty that may be available, a non-U.S. holder will be required to provide a properly executed IRS Form W-8BEN or W-8BEN-E (or suitable substitute form). Prospective investors should consult their own tax advisors concerning the U.S. tax treatment of contract adjustment payments.

Sale, Exchange, or Other Disposition of Equity Units, Applicable Ownership Interests in NEE Capital Debentures, Purchase Contracts, Treasury Securities, the Applicable Ownership Interest in the Treasury Portfolio or NEE Common Stock

Except as provided below under “—Backup Withholding and Information Reporting,” any gain recognized by a non-U.S. holder upon the sale, exchange, or other disposition of Equity Units, applicable ownership interests in NEE Capital Debentures, purchase contracts, Treasury securities, the applicable ownership interest in the Treasury portfolio, or NEE common stock generally will not be subject to U.S. federal income tax, unless (1) the non-U.S. holder is an individual who is present in the United States for 183 days or more during the taxable year in which the disposition takes place and certain other conditions are met or (2) in the case of purchase contracts or shares of NEE’s common stock, such purchase contracts or shares of NEE’s common stock are considered “United States real property interests” for U.S. federal income tax purposes. Purchase contracts or NEE common stock generally will be treated as United States real property interests if NEE is (or, during a specified period, has been) a “United States real property holding corporation” for U.S. federal income tax purposes. NEE believes that it has not been and currently is not a United States real property holding corporation, and NEE does not expect to become one in the future based on anticipated business operations.

Backup Withholding and Information Reporting

In general, no information reporting or backup withholding will be required with respect to payments made by NEE on the Equity Units or applicable ownership interests in the NEE Capital debentures if the non-U.S. holder has provided NEE with a properly executed IRS Form W-8BEN or W-8BEN-E (or suitable substitute form) and NEE does not have actual knowledge or reason to know that the non-U.S. holder is a U.S. person. In addition, no information reporting or backup withholding will be required with respect to proceeds from a disposition of Equity Units, applicable ownership interests in NEE Capital debentures, Treasury securities, the applicable ownership interest in the Treasury portfolio, or NEE common stock (even if the disposition is considered to be effected within the United States or through a U.S. financial intermediary) if the payor receives a properly executed IRS Form W-8BEN or W-8BEN-E (or suitable substitute form) and does not have actual knowledge or reason to know that the non-U.S. holder is a U.S. person, or an exemption is otherwise established. Any amounts withheld under the backup withholding tax rules will be creditable against the non-U.S. holder’s U.S. federal income tax liability, or allowed as a refund, provided that the required information is timely and properly provided to the IRS.

Additional Withholding Requirements

Pursuant to the Foreign Account Tax Compliance Act, or “FATCA,” and the Treasury Regulations promulgated thereunder, the relevant withholding agent may be required to withhold 30% of any “withholdable

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payments,” which would include any interest (including OID), dividends and contract adjustment payments to (1) a foreign financial institution unless such foreign financial institution agrees to verify, report and disclose its holders of U.S. accounts and meets certain other specified requirements or (2) a non-financial foreign entity that is the beneficial owner of the payment unless such entity certifies that it does not have any substantial U.S. owners or provides the name, address and taxpayer identification number of each substantial U.S. owner and such entity meets certain other specified requirements. Under certain circumstances, a non-U.S. holder may be eligible for refunds or credits of the tax. An intergovernmental agreement between the United States and an applicable foreign country may modify the requirements described in this paragraph. Prospective non-U.S. holders should consult with their own tax advisors regarding the possible implications of FATCA on their investment in the Equity Units.

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Annex A

	4.872% Corporate Units	5.279% Corporate Units	6.219% Corporate Units
Closing Date	September 9, 2019	February 21, 2020	September 18, 2020
Contract Adjustment Annualized Amount	$1.386	$1.7195	$2.855
Contract Adjustment Rate	2.772%	3.439%	5.710%
Corporate Unit Aggregate Rate	4.872%	5.279%	6.219%
Day Before the Three Month Date	May 31, 2022	November 30, 2022	May 31, 2023
Fundamental Change Early Settlement Table High Price (1)	$490	$500	$600
Fundamental Change Early Settlement Table Low Price (1)	$100	$25	$25
Initial Interest Annualized Amount	$1.05	$0.92	$0.2545
Initial Interest Rate	2.10%	1.84%	0.509%
Initial Payment Date	December 1, 2019	June 1, 2020	December 1, 2020
Maximum Settlement Rate (2)	0.8973	0.7104	0.6776
Minimum Number	80,000	100,000	400,000
Minimum Settlement Rate (2)	0.7181	0.5681	0.5421
NEE Capital Debenture Fair Market Value	$48.75	$48.75	$48.60
NEE Capital Debenture Maturity Date	September 1, 2024	March 1, 2025	September 1, 2025
NEE Capital Related Debenture	NEE Capital Series J Debenture due September 1, 2024	NEE Capital Series K Debenture due March 1, 2025	NEE Capital Series L Debenture due September 1, 2025
Purchase Contract Settlement Date	September 1, 2022	March 1, 2023	September 1, 2023
Reference Dividend (2)	$0.3125	$0.35	$0.35
Reference Price (2)	$55.72	$70.39	$73.79
Six Month Date	March 1, 2022	September 1, 2022	March 1, 2023

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Tax Event Measurement Date	September 5, 2019	February 19, 2020	September 16, 2020
Three Month Date	June 1, 2022	December 1, 2022	June 1, 2023
Threshold Appreciation Price (2)	$69.66	$87.99	$92.24
Treasury Portfolio Maturity Deadline	August 31, 2022	February 28, 2023	August 31, 2023
Zero-Coupon CUSIP	CUSIP No. 912820X28	CUSIP No. 9128284A5	CUSIP No. 9128284X5

Notes to Table:

(1)    See Note (a) to the Fundamental Change Early Settlement Tables below.

(2)    As a result of the four-for-one stock split of NEE’s common stock effective in October 2020 (“2020 stock split”) and other adjustments related to the dividend rate, the fixed settlement rates and the reference dividends set forth in the preceding table have been adjusted. In addition, the applicable market value for each series of Corporate Units will also be adjusted (when determined) to give effect to the 2020 stock split and certain other anti-dilution adjustments to determine the applicable settlement rate. However, for purposes of the presentation above, corresponding adjustments were instead made to the reference prices and the threshold appreciation prices for each series of Corporate Units to present the practical effect of the anti-dilution adjustments as of the Description Date.

Fundamental Change Early Settlement Table for 4.872% Equity Units (a)

	Effective Date
Stock Price	September 1, 2020	September 1, 2021	September 1, 2022
$100.00	0.0236	0.0119	0.0000
$130.00	0.0176	0.0089	0.0000
$160.00	0.0131	0.0069	0.0000
$190.00	0.0069	0.0038	0.0000
$224.12	0.0000	0.0000	0.0000
$250.00	0.0093	0.0050	0.0000
$280.15	0.0210	0.0145	0.0000
$310.00	0.0141	0.0075	0.0000
$340.00	0.0099	0.0046	0.0000
$370.00	0.0076	0.0034	0.0000
$400.00	0.0062	0.0029	0.0000
$430.00	0.0054	0.0026	0.0000
$460.00	0.0048	0.0024	0.0000
$490.00	0.0044	0.0022	0.0000

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Fundamental Change Early Settlement Table for 5.279% Equity Units (a)

	Effective Date
Stock Price	February 21, 2020	March 1, 2021	March 1, 2022	March 1, 2023
$25.00	0.1829	0.1540	0.0907	0.0000
$50.00	0.0901	0.0761	0.0449	0.0000
$100.00	0.0437	0.0372	0.0220	0.0000
$150.00	0.0281	0.0242	0.0144	0.0000
$200.00	0.0186	0.0166	0.0104	0.0000
$250.00	0.0083	0.0075	0.0046	0.0000
$282.04	0.0000	0.0000	0.0000	0.0000
$300.00	0.0078	0.0064	0.0028	0.0000
$325.00	0.0156	0.0136	0.0088	0.0000
$352.55	0.0228	0.0203	0.0145	0.0000
$400.00	0.0165	0.0138	0.0081	0.0000
$450.00	0.0123	0.0099	0.0054	0.0000
$500.00	0.0097	0.0078	0.0044	0.0000

Fundamental Change Early Settlement Table for 6.219% Equity Units (a)

	Effective Date
Stock Price	September 18, 2020	September 1, 2021	September 1, 2022	September 1, 2023
$25.00	0.2832	0.1839	0.0890	0.0000
$50.00	0.1336	0.0877	0.0431	0.0000
$100.00	0.0633	0.0420	0.0209	0.0000
$150.00	0.0389	0.0263	0.0135	0.0000
$250.00	0.0110	0.0052	0.0010	0.0000
$295.70	0.0000	0.0000	0.0000	0.0000
$325.00	0.0124	0.0072	0.0024	0.0000
$369.63	0.0251	0.0199	0.0142	0.0000
$400.00	0.0219	0.0168	0.0109	0.0000
$450.00	0.0178	0.0129	0.0072	0.0000
$500.00	0.0148	0.0103	0.0052	0.0000
$550.00	0.0125	0.0085	0.0041	0.0000
$600.00	0.0108	0.0072	0.0034	0.0000

Note to Fundamental Change Early Settlement Tables:

(a)    Although the Corporate Units provide that the stock prices and make-whole amounts in the tables will be adjusted upon the occurrence of certain events requiring adjustment to each fixed settlement rate, for purposes of the presentation above the stock prices and make-whole amounts have not been adjusted.

III.    JUNIOR SUBORDINATED DEBENTURES

DESCRIPTION OF THE NEE CAPITAL JUNIOR SUBORDINATED DEBENTURES AND
NEE JUNIOR SUBORDINATED GUARANTEE

This section briefly summarizes some of the terms of the Junior Subordinated Debentures, NEE’s junior subordinated guarantee of the Junior Subordinated Debentures (the “Junior Subordinated Guarantee”), and some of the provisions of the Junior Subordinated Indenture (as defined below). This summary does not contain a complete description of the Junior Subordinated Debentures, the Junior Subordinated Guarantee or the Junior Subordinated Indenture. You should read this summary together with the Junior Subordinated Indenture and the officer’s certificates creating the Junior Subordinated Debentures and the Junior Subordinated Guarantee for a complete understanding of all the provisions and for the definitions of some terms used in this summary. The Junior Subordinated Indenture which includes the Junior Subordinated Guarantee and the officer’s certificates creating the specific terms of the Junior Subordinated Debentures have previously been filed with the SEC, and are exhibits to the Form 10-K. In addition, the Subordinated Indenture is qualified under the Trust Indenture Act of 1939 and

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therefore subject to the provisions of the Trust Indenture Act of 1939. You should read the Trust Indenture Act of 1939 for a complete understanding of its provisions.

General. NEE Capital has issued $687,500,000 aggregate principal amount of its Series N Junior Subordinated Debentures due March 1, 2079 (the “Junior Subordinated Debentures”). The Junior Subordinated Debentures were issued under an indenture, dated as of September 1, 2006, as amended, referred to as the “Junior Subordinated Indenture,” among NEE Capital, NEE, as guarantor, and The Bank of New York Mellon, as subordinated indenture trustee, referred to as “Subordinated Indenture Trustee.” An officer’s certificate supplemented the Junior Subordinated Indenture and created the specific terms of the Junior Subordinated Debentures. Under the Junior Subordinated Indenture, NEE Capital may issue an unlimited amount of additional unsecured subordinated debt securities. The Junior Subordinated Debentures and all other unsecured subordinated debentures, or other debt of NEE Capital issued previously or hereinafter under the Junior Subordinated Indenture are collectively referred to as “Junior Subordinated Indenture Securities.” The Subordinated Indenture does not limit the aggregate amount of indebtedness that NEE Capital, NEE or their respective subsidiaries may issue, guarantee or otherwise incur.

The Junior Subordinated Debentures were issued in minimum denominations of $25 and integral multiples thereof. NEE Capital’s corporate parent, NEE, unconditionally and irrevocably guarantees the payment of principal, interest and premium, if any, on the Junior Subordinated Debentures. See “—Junior Subordinated Guarantee of Junior Subordinated Debentures.” All Junior Subordinated Debentures of one series need not be issued at the same time, and a series may be re-opened for issuances of additional NEE Capital Subordinated Debentures. This means that NEE Capital may from time to time, without notice to, or the consent of any existing holders of the previously-issued Junior Subordinated Debentures of a particular series, create and issue additional Junior Subordinated Debentures. Such additional Junior Subordinated Debentures will have the same terms as the previously-issued Junior Subordinated Debentures in all respects except for the issue date and, if applicable, the initial interest payment date. The additional Junior Subordinated Debentures will be consolidated and form a single series with the previously-issued Junior Subordinated Debentures.

The Subordinated Indenture Trustee is initially the security registrar and the paying agent for the Junior Subordinated Debentures. All transactions with respect to the Junior Subordinated Debentures, including registration, transfer and exchange of the Junior Subordinated Debentures, will be handled by the security registrar at an office in New York City designated by NEE Capital. NEE Capital has initially designated the corporate trust office of the Subordinated Indenture Trustee as that office. In addition, holders of the Junior Subordinated Debentures should address any notices to NEE Capital regarding the Junior Subordinated Debentures to that office. NEE Capital will notify holders of the Junior Subordinated Debentures of any change in the location of that office.

Interest and Payment. NEE Capital will pay interest quarterly on the Junior Subordinated Debentures at the rate of 5.65% per year. The Junior Subordinated Debentures will mature on March 1, 2079. NEE Capital will pay interest on the Junior Subordinated Debentures on March 1, June 1, September 1 and December 1 of each year, each such date referred to as an “interest payment date,” until maturity or earlier redemption. The first interest payment date on the Subordinated Debentures was June 1, 2019. The record date for interest payable on any interest payment date for the Junior Subordinated Debentures is the close of business on (1) the business day immediately preceding such interest payment date so long as all of the Junior Subordinated Debentures remain in book-entry only form, or (2) the 15th calendar day immediately preceding such interest payment date if any of the Junior Subordinated Debentures do not remain in book-entry only form. See “— Book-Entry Only Issuance.” Interest on the Junior Subordinated Debentures accrued from and including the date of original issuance to but excluding the first interest payment date. Starting on the first interest payment date, interest on each Junior Subordinated Debenture will accrue from and including the last interest payment date to which NEE Capital has paid, or duly provided for the payment of, interest on that Junior Subordinated Debenture to but excluding the next succeeding interest payment date. No interest will accrue on a Junior Subordinated Debenture for the day that the Junior Subordinated Debenture matures. The amount of interest payable for any period will be computed on the basis of a 360-day year consisting of twelve 30-day months. The amount of interest payable for any period shorter than a full quarterly period for which interest is computed will be computed on the basis of the number of days in the period using 30-day calendar months. If any date on which interest, principal or premium, if any, is payable on the Junior Subordinated Debentures falls on a day that is not a business day, then payment of the interest, principal or premium payable on that date will be made on the next succeeding day which is a business day, and no interest will be paid or other payment made in respect of such delay. A “business day” is any day that is not a Saturday, a Sunday, or a day on which banking institutions or trust companies in New York City are generally authorized or required by law or executive order to remain closed.

In this “Description of the NEE Capital Junior Subordinated Debentures and NEE Junior Subordinated Guarantee” the term “interest” includes quarterly interest payments and applicable interest on interest payments accrued but not paid on the applicable interest payment date.

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Ranking of the Junior Subordinated Debentures and the Junior Subordinated Guarantee. NEE Capital’s payment obligations under the Junior Subordinated Debentures are unsecured and rank junior and are subordinated in right of payment and upon liquidation to all of NEE Capital’s Senior Indebtedness, and NEE’s payment obligation under the Junior Subordinated Guarantee is unsecured and ranks junior and is subordinated in right of payment and upon liquidation to all of NEE’s Senior Indebtedness. However, the Junior Subordinated Debentures and the Junior Subordinated Guarantee ranks equally in right of payment with any Pari Passu Securities.

“Senior Indebtedness,” when used with respect to NEE Capital or NEE, means all of NEE Capital’s or NEE’s obligations, as the case may be, whether presently existing or from time to time hereafter incurred, created, assumed or existing, to pay principal, premium, interest, penalties, fees and any other payment in respect of any of the following:

•obligations for borrowed money, including without limitation, such obligations as are evidenced by credit agreements, notes, debentures, bonds or other securities or instruments;

•capitalized lease obligations;

•all obligations of the types referred to in the two preceding bullet points of others which NEE or NEE Capital, as the case may be, has assumed, endorsed, guaranteed, contingently agreed to purchase or provide funds for the payment of, or otherwise becomes liable for, under any agreement; or

•all renewals, extensions or refundings of obligations of the kinds described in any of the preceding categories.

Any such obligation, indebtedness, renewal, extension or refunding, however, will not be Senior Indebtedness if the instrument creating or evidencing it or the assumption or guarantee of it provides that it is not superior in right of payment to or is equal in right of payment with the Junior Subordinated Debentures or the Junior Subordinated Guarantee, as the case may be. Furthermore, trade accounts payable and accrued liabilities arising in the ordinary course of business will not be Senior Indebtedness. Senior Indebtedness will be entitled to the benefits of the subordination provisions in the Junior Subordinated Indenture irrespective of the amendment, modification or waiver of any term of the Senior Indebtedness.

No payment of the principal (including redemption and sinking fund payments) of, or interest, or premium, if any, on the Junior Subordinated Debentures of any series may be made by NEE Capital until all holders of Senior Indebtedness have been paid in full (or provision has been made for such payment), if any of the following occurs:

•certain events of bankruptcy, insolvency or reorganization of NEE Capital;

•any Senior Indebtedness of NEE Capital is not paid when due (after the expiration of any applicable grace period) and that default continues without waiver; or

•any other default has occurred and continues without waiver (after the expiration of any applicable grace period) pursuant to which the holders of Senior Indebtedness of NEE Capital are permitted to accelerate the maturity of such Senior Indebtedness.

Upon any distribution of assets of NEE Capital to creditors in connection with any insolvency, bankruptcy or similar proceeding, all principal of, and premium, if any, and interest due or to become due on all Senior Indebtedness of NEE Capital must be paid in full before the holders of the Junior Subordinated Debentures are entitled to receive or retain any payment from such distribution. See “ — Subordination” below.

“Pari Passu Securities” means:

•indebtedness and other securities that, among other things, by its terms ranks equally with the Junior Subordinated Debentures, with respect to NEE Capital, and the Junior Subordinated Guarantee, with respect to NEE, in right of payment and upon liquidation; and

•guarantees of indebtedness or other securities described in the preceding bullet point.

“Pari Passu Securities” also include NEE Capital’s trade accounts payable and accrued liabilities arising in the ordinary course of business.

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While NEE Capital is a holding company that derives substantially all of its income from its operating subsidiaries, NEE Capital’s subsidiaries are separate and distinct legal entities and have no obligation to make any payments on the Junior Subordinated Debentures of any series or to make any funds available for such payment. Therefore, the Junior Subordinated Debentures will be effectively subordinated to all indebtedness and other liabilities, including trade payables, debt and preferred stock, incurred or issued by NEE Capital’s subsidiaries. In addition to trade liabilities, many of NEE Capital’s operating subsidiaries incur debt in order to finance their business activities. All of this indebtedness will be effectively senior to the Junior Subordinated Debentures. The Junior Subordinated Indenture does not place any limit on the amount of Senior Indebtedness that NEE Capital may issue, guarantee or otherwise incur or the amount of liabilities, including debt or preferred stock, that NEE Capital’s subsidiaries may issue, guarantee or otherwise incur. NEE Capital expects from time to time to incur additional indebtedness and other liabilities and to guarantee indebtedness that will be senior to the Junior Subordinated Debentures. At December 31, 2021, NEE Capital’s Senior Indebtedness, on an unconsolidated basis, totaled approximately $23.7 billion.

While NEE is a holding company that derives substantially all of its income from its operating subsidiaries, NEE’s subsidiaries are separate and distinct legal entities and, other than NEE Capital, have no obligation to make any payments on the Junior Subordinated Debentures of any series or to make any funds available for such payment. Therefore, the Junior Subordinated Guarantee will be effectively subordinated to all indebtedness and other liabilities, including trade payables, debt and preferred stock incurred or issued by NEE’s subsidiaries. In addition to trade liabilities, many of NEE’s operating subsidiaries incur debt in order to finance their business activities. All of this indebtedness will be effectively senior to the Junior Subordinated Guarantee. The Junior Subordinated Indenture does not place any limit on the amount of Senior Indebtedness that NEE may issue, guarantee or otherwise incur or the amount of liabilities, including debt or preferred stock, that NEE’s subsidiaries may issue, guarantee or otherwise incur. NEE expects from time to time to incur additional indebtedness and other liabilities and to guarantee indebtedness that will be senior to the Junior Subordinated Guarantee. At December 31, 2021, NEE’s Senior Indebtedness, on an unconsolidated basis, totaled approximately $24.0 billion, which amount consisted solely of NEE’s guarantees of NEE Capital indebtedness referred to in the paragraph above.

Optional Redemption. NEE Capital may redeem some or all of the Junior Subordinated Debentures, at its option, at any time or from time to time, as described below (each a “Redemption Date”). NEE Capital will give notice of its intent to redeem some or all of the Junior Subordinated Debentures at least 30 but no more than 60 days prior to the Redemption Date.

If NEE Capital redeems all or any part of the Junior Subordinated Debentures at any time on or after June 15, 2024, it will pay a redemption price equal to 100% of the principal amount of the Junior Subordinated Debentures being redeemed, plus accrued and unpaid interest thereon, if any, to but excluding the Redemption Date.

If NEE Capital at any time elects to redeem some but not all of the Junior Subordinated Debentures of a particular series, the Subordinated Indenture Trustee will select the particular Junior Subordinated Debentures to be redeemed using any method that it deems fair and appropriate. However, if the Junior Subordinated Debentures are solely registered in the name of Cede & Co. and traded through DTC, then DTC will select the Junior Subordinated Debentures of the particular series to be redeemed in accordance with its practices as described below in “— Book-Entry Only Issuance.”

If at the time notice of redemption is given, the redemption moneys are not on deposit with the Subordinated Indenture Trustee, then, if such notice so provides, the redemption shall be subject to the receipt of the redemption moneys on or before the Redemption Date and such notice of redemption shall be of no force or effect unless such moneys are received.

Right to Redeem Upon a Tax Event. NEE Capital may redeem, upon a Redemption Notice, in whole but not in part, the Junior Subordinated Debentures, at any time within 90 days after there is a Tax Event (as defined below) before June 15, 2024, at the redemption price equal to the sum of: (1) 100% of the principal amount of the Junior Subordinated Debentures plus (2) accrued and unpaid interest thereon, if any, to but excluding the date fixed for redemption (“Tax Event Redemption Date”).

The consummation of a redemption upon a Tax Event may be subject to the Subordinated Indenture Trustee’s receipt of the required redemption moneys on or before the Tax Event Redemption Date (and in such case no such redemption shall occur unless such moneys have been received by the Subordinated Indenture Trustee on or before such date).

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A “Tax Event” happens when NEE or NEE Capital has received an opinion of counsel experienced in tax matters that, as a result of:

•any amendment to, clarification of, or change, including any announced prospective change, in the laws or treaties of the United States or any of its political subdivisions or taxing authorities, or any regulations under those laws or treaties;

•an administrative action, which means any judicial decision or any official administrative pronouncement, ruling, regulatory procedure, notice or announcement including any notice or announcement of intent to issue or adopt any administrative pronouncement, ruling, regulatory procedure or regulation;

•any amendment to, clarification of, or change in the official position or the interpretation of any administrative action or judicial decision or any interpretation or pronouncement that provides for a position with respect to an administrative action or judicial decision that differs from the previously generally accepted position, in each case by any legislative body, court, governmental authority or regulatory body, regardless of the time or manner in which that amendment, clarification or change is introduced or made known; or

•a threatened challenge asserted in writing in connection with an audit of NEE or NEE Capital or any of their subsidiaries, or a publicly-known threatened challenge asserted in writing against any other taxpayer that has raised capital through the issuance of securities that are substantially similar to the Junior Subordinated Debentures,

which amendment, clarification, or change is effective or the administrative action is taken or judicial decision, interpretation or pronouncement is issued or threatened challenge is asserted or becomes publicly-known after March 6, 2019, there is more than an insubstantial risk that interest payable by NEE Capital on the Junior Subordinated Debentures is not deductible, or within 90 days would not be deductible, in whole or in part, by NEE Capital for United States federal income tax purposes.

Right to Redeem Upon a Rating Agency Event. NEE Capital may, upon a Redemption Notice given at any time within 90 days after the conclusion of any review or appeal process instituted by NEE Capital or NEE following the occurrence of a Rating Agency Event (as defined below), redeem the Junior Subordinated Debentures in whole but not in part before June 15, 2024, at the redemption price equal to the sum of  (1) 102% of the principal amount of the Junior Subordinated Debentures plus (2) accrued and unpaid interest thereon, if any, to but excluding the date fixed for redemption (“Rating Agency Event Redemption Date”).

The consummation of a redemption upon a Rating Agency Event may be subject to the Subordinated Indenture Trustee’s receipt of the required redemption moneys on or before the Rating Agency Event Redemption Date (and in such case no such redemption shall occur unless such moneys have been received by the Subordinated Indenture Trustee on or before such date).

“Rating Agency Event” means a change to the methodology or criteria that were employed by an applicable rating agency (as defined below) for purposes of assigning equity credit to securities such as the Junior Subordinated Debentures on the date of initial issuance of the Junior Subordinated Debentures (the “current methodology”), which change reduces the amount of equity credit assigned to the Junior Subordinated Debentures by the applicable rating agency as compared with the amount of equity credit that such rating agency had assigned to the Junior Subordinated Debentures as of the date of initial issuance thereof.

The term “rating agency” means any nationally recognized statistical rating organization (within the meaning of Section 3(a)(62) of the Securities Exchange Act of 1934 and sometimes referred to as a “rating agency”), and the term “applicable rating agency” means any rating agency that (i)(a) published a rating for NEE Capital or NEE with respect to the initial issuance of the Junior Subordinated Debentures and (b) publishes a rating for NEE Capital or NEE at such time as a Rating Agency Event occurs, or (ii) any successor to a rating agency described in the preceding clause (i).

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Other Redemption Provisions. The Junior Subordinated Debentures of any series selected for redemption will cease to bear interest on the applicable redemption date. The paying agent will pay the redemption price and any accrued interest once the Junior Subordinated Debentures are surrendered for redemption. (Junior Subordinated Indenture, Section 405). On the redemption date NEE Capital will pay interest on the Junior Subordinated Debentures being redeemed to the person to whom it pays the redemption price. If only part of a Junior Subordinated Debenture is redeemed, the Junior Subordinated Indenture Trustee will deliver a new Junior Subordinated Debenture of the same series for the remaining portion without charge. (Junior Subordinated Indenture, Section 406).

Purchase of Junior Subordinated Debentures. NEE or its affiliates, including NEE Capital, may at any time and from time to time, purchase all or some of the Junior Subordinated Debentures at any price or prices, whether by tender, in the open market, by private agreement or otherwise, subject to applicable law.

Option to Defer Interest Payments. So long as there is no event of default under the Junior Subordinated Indenture, NEE Capital may defer interest payments on the Junior Subordinated Debentures, from time to time, for one or more Optional Deferral Periods of up to 10 consecutive years per Optional Deferral Period. However, a deferral of interest payments cannot extend beyond the maturity date of the Junior Subordinated Debentures. During an Optional Deferral Period, interest will continue to accrue on the Junior Subordinated Debentures, compounded quarterly, and deferred interest payments will accrue additional interest at a rate equal to the interest rate on the Junior Subordinated Debentures, to the extent permitted by applicable law. No interest will be due and payable on the Junior Subordinated Debentures until the end of the Optional Deferral Period except upon a redemption of the Junior Subordinated Debentures during the deferral period.

At the end of the Optional Deferral Period or on any redemption date, NEE Capital will be obligated to pay all accrued and unpaid interest.

Once all accrued and unpaid interest on the Junior Subordinated Debentures has been paid, NEE Capital again can defer interest payments on the Junior Subordinated Debentures as described above, provided that an Optional Deferral Period cannot extend beyond the maturity date of the Junior Subordinated Debentures.

If NEE Capital defers interest for a period of 10 consecutive years from the commencement of an Optional Deferral Period, NEE Capital will be required to pay all accrued and unpaid interest at the conclusion of the 10-year period, and to the extent it does not do so, NEE will be required to make guarantee payments in accordance with the Junior Subordinated Guarantee with respect thereto. If NEE Capital fails to pay in full all accrued and unpaid interest at the conclusion of the 10-year period, such failure continues for 30 days and NEE fails to make guarantee payments with respect thereto, an event of default that gives rise to a right to accelerate principal of and interest on the Junior Subordinated Debentures will have occurred under the Junior Subordinated Indenture. See “ — Events of Default” and “ — Remedies.”

During any period in which NEE Capital defers interest payments on the Junior Subordinated Debentures of any series, neither NEE nor NEE Capital will, and each will cause their majority-owned subsidiaries not to, do any of the following:

•declare or pay any dividend or distribution on NEE’s or NEE Capital’s capital stock;

•redeem, purchase, acquire or make a liquidation payment with respect to any of NEE’s or NEE Capital’s capital stock;

•pay any principal, interest or premium on, or repay, repurchase or redeem any of NEE’s or NEE Capital’s debt securities that are equal or junior in right of payment with the Junior Subordinated Debentures or the Junior Subordinated Guarantee (as the case may be); or

•make any payments with respect to any NEE or NEE Capital guarantee of debt securities if such guarantee is equal or junior in right of payment to the Junior Subordinated Debentures or the Junior Subordinated Guarantee (as the case may be),

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other than

(a)    purchases, redemptions or other acquisitions of its capital stock in connection with any employment contract, benefit plan or other similar arrangement with or for the benefit of employees, officers, directors or agents or a stock purchase or dividend reinvestment plan, or the satisfaction of its obligations pursuant to any contract or security outstanding on the date that the payment of interest is deferred requiring it to purchase, redeem or acquire its capital stock,

(b)    any payment, repayment, redemption, purchase, acquisition or declaration of dividend listed as restricted payments in clauses (1) and (2) above as a result of a reclassification of its capital stock or the exchange or conversion of all or a portion of one class or series of its capital stock for another class or series of its capital stock,

(c)    the purchase of fractional interests in shares of its capital stock pursuant to the conversion or exchange provisions of its capital stock or the security being converted or exchanged, or in connection with the settlement of stock purchase contracts,

(d)    dividends or distributions paid or made in its capital stock (or rights to acquire its capital stock), or repurchases, redemptions or acquisitions of capital stock in connection with the issuance or exchange of capital stock (or of securities convertible into or exchangeable for shares of its capital stock) and distributions in connection with the settlement of stock purchase contracts,

(e)    redemptions, exchanges or repurchases of, or with respect to, any rights outstanding under a shareholder rights plan or the declaration or payment thereunder of a dividend or distribution of or with respect to rights in the future,

(f)    payments under any preferred trust securities guarantee or guarantee of subordinated debentures executed and delivered by NEE concurrently with the issuance by a trust of any preferred trust securities, so long as the amount of payments made with respect to any preferred trust securities or subordinated debentures (as the case may be) is paid on all preferred trust securities or subordinated debentures (as the case may be) then outstanding on a pro rata basis in proportion to the full distributions to which each series of preferred trust securities or subordinated debentures (as the case may be) is then entitled if paid in full,

(g)    payments under any guarantee of junior subordinated debentures executed and delivered by NEE (including the Junior Subordinated Guarantee), so long as the amount of payments made on any junior subordinated debentures is paid on all junior subordinated debentures then outstanding on a pro rata basis in proportion to the full payment to which each series of junior subordinated debentures is then entitled if paid in full,

(h)    dividends or distributions by NEE Capital on its capital stock to the extent owned by NEE, or

(i)    redemptions, purchases, acquisitions or liquidation payments by NEE Capital with respect to its capital stock to the extent owned by NEE. (Junior Subordinated Indenture, Section 608).

NEE and NEE Capital have reserved the right to amend the Junior Subordinated Indenture, without the consent or action of the holders of any Junior Subordinated Indenture Securities issued after October 1, 2006, including the Junior Subordinated Debentures, to modify the exceptions to the restrictions described in clause (f) above to allow payments with respect to any preferred trust securities or debt securities, or any guarantee thereof (including the Junior Subordinated Guarantee), executed and delivered by NEE, NEE Capital or any of their subsidiaries, in each case that rank equal in right of payment to such junior subordinated debentures or the related guarantee, as the case may be, so long as the amount of payments made on account of such securities or guarantees is paid on all such securities or guarantees then outstanding on a pro rata basis in proportion to the full payment to which each series of such securities or guarantees is then entitled if paid in full.

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Before an optional deferral period ends, NEE Capital may further defer the payment of interest and after any optional deferral period and the payment of all amounts then due, NEE Capital may select a new optional deferral period. No optional deferral period may exceed the period of time specified herein. No interest period may be deferred beyond the maturity of the Junior Subordinated Debentures.

Modification of the Junior Subordinated Indenture. NEE and NEE Capital have reserved the right to amend the Junior Subordinated Indenture without the consent or action of the holders of any junior subordinated debentures issued after October 1, 2006, including the Junior Subordinated Debentures, to modify the exceptions to the restrictions described above under “— Option to Defer Interest Payments” applicable during any period in which NEE Capital defers interest payments on such junior subordinated debentures (including the Junior Subordinated Debentures) to allow payments with respect to any preferred trust securities or debt securities, or any guarantee thereof  (including the Junior Subordinated Guarantee), executed and delivered by NEE, NEE Capital or any of their majority-owned subsidiaries, in each case that rank equal in right of payment to such junior subordinated debentures or the related guarantee, as the case may be, so long as the amount of payments made on account of such securities or guarantees is paid on all such securities or guarantees then outstanding on a pro rata basis in proportion to the full payment to which each series of such securities or guarantees is then entitled if paid in full.

Subordination. The Junior Subordinated Debentures will be subordinate and junior in right of payment to all Senior Indebtedness of NEE Capital. (Junior Subordinated Indenture, Article Fifteen). No payment of the principal (including redemption and sinking fund payments) of, or interest, or premium, if any, on the Junior Subordinated Debentures may be made by NEE Capital, until all holders of Senior Indebtedness of NEE Capital have been paid in full (or provision has been made for such payment), if any of the following occurs:

(1)    certain events of bankruptcy, insolvency or reorganization of NEE Capital,

(2)    any Senior Indebtedness of NEE Capital is not paid when due (after the expiration of any applicable grace period) and that default continues without waiver, or

(3)    any other default has occurred and continues without waiver (after the expiration of any applicable grace period) pursuant to which the holders of Senior Indebtedness of NEE Capital are permitted to accelerate the maturity of such Senior Indebtedness. (Junior Subordinated Indenture, Section 1502).

Upon any distribution of assets of NEE Capital to creditors in connection with any insolvency, bankruptcy or similar proceeding, all principal of, and premium, if any, and interest due or to become due on all Senior Indebtedness of NEE Capital must be paid in full before the holders of the Junior Subordinated Debentures are entitled to receive or retain any payment from such distribution. (Junior Subordinated Indenture, Section 1502).

While NEE Capital is a holding company that derives substantially all of its income from its operating subsidiaries, NEE Capital’s subsidiaries are separate and distinct legal entities and have no obligation to make any payments on the Junior Subordinated Indenture Securities or to make any funds available for such payment. Therefore, Junior Subordinated Indenture Securities will effectively be subordinated to all indebtedness and other liabilities, including trade payables, debt and preferred stock, incurred or issued by NEE Capital’s subsidiaries. In addition to trade liabilities, many of NEE Capital’s operating subsidiaries incur debt in order to finance their business activities. All of this indebtedness will effectively be senior to the Junior Subordinated Indenture Securities. The Junior Subordinated Indenture does not place any limit on the amount of liabilities, including debt or preferred stock, that NEE Capital’s subsidiaries may issue, guarantee or incur.

Junior Subordinated Guarantee of Junior Subordinated Debentures. Pursuant to the Junior Subordinated Guarantee, NEE will absolutely, irrevocably and unconditionally guarantee the payment of principal of and any interest and premium, if any, on the Junior Subordinated Debentures, when due and payable, whether at the stated maturity date, by declaration of acceleration, call for redemption or otherwise, in accordance with the terms of such Junior Subordinated Debentures and the Junior Subordinated Indenture. The Junior Subordinated Guarantee will remain in effect until the entire principal of and any premium, if any, and interest on the Junior Subordinated Debentures has been paid in full or otherwise discharged in accordance with the provisions of the Junior Subordinated Indenture. (Junior Subordinated Indenture, Article Fourteen).

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The Junior Subordinated Guarantee will be subordinate and junior in right of payment to all Senior Indebtedness of NEE. (Junior Subordinated Indenture, Section 1402). No payment of the principal (including redemption and sinking fund payments) of, or interest, or premium, if any, on, the Junior Subordinated Debentures may be made by NEE under the Junior Subordinated Guarantee until all holders of Senior Indebtedness of NEE have been paid in full (or provision has been made for such payment), if any of the following occurs:

(1)    certain events of bankruptcy, insolvency or reorganization of NEE,

(2)    any Senior Indebtedness of NEE is not paid when due (after the expiration of any applicable grace period) and that default continues without waiver, or

(3)    any other default has occurred and continues without waiver (after the expiration of any applicable grace period) pursuant to which the holders of Senior Indebtedness of NEE are permitted to accelerate the maturity of such Senior Indebtedness. (Junior Subordinated Indenture, Section 1403).

Upon any distribution of assets of NEE to creditors in connection with any insolvency, bankruptcy or similar proceeding, all principal of, and premium, if any, and interest due or to become due on all Senior Indebtedness of NEE must be paid in full before the holders of the Junior Subordinated Debentures are entitled to receive or retain any payment from such distribution. (Junior Subordinated Indenture, Section 1403).

While NEE is a holding company that derives substantially all of its income from its operating subsidiaries, NEE’s subsidiaries are separate and distinct legal entities and have no obligation to make any payments under the Junior Subordinated Guarantee or to make any funds available for such payment. Therefore, the Junior Subordinated Guarantee will effectively be subordinated to all indebtedness and other liabilities, including trade payables, debt and preferred stock, incurred or issued by NEE’s subsidiaries. In addition to trade liabilities, many of NEE’s operating subsidiaries incur debt in order to finance their business activities. All of this indebtedness will effectively be senior to the Junior Subordinated Guarantee. The Junior Subordinated Indenture does not place any limit on the amount of liabilities, including debt or preferred stock, that NEE’s subsidiaries may issue, guarantee or incur. See “Description of NEE Common Stock—Common Stock Terms—Dividend Rights” for a description of contractual restrictions on the dividend-paying ability of some of NEE’s subsidiaries.

Payment and Paying Agents. On each interest payment date NEE Capital will pay interest on each Junior Subordinated Debenture to the person in whose name that Junior Subordinated Debenture is registered as of the close of business on the record date relating to that interest payment date. However, on the date that the Junior Subordinated Debentures mature, NEE Capital will pay the interest to the person to whom it pays the principal. Also, if NEE Capital has defaulted in the payment of interest on any Junior Subordinated Debenture, it may pay that defaulted interest to the registered owner of that Junior Subordinated Debenture:

(1)    as of the close of business on a date that the Junior Subordinated Indenture Trustee selects, which may not be more than 15 days or less than 10 days before the date that NEE Capital, or NEE, as the case may be, proposes to pay the defaulted interest, or

(2)    in any other lawful manner that does not violate the requirements of any securities exchange on which that Junior Subordinated Debenture is listed and that the Junior Subordinated Indenture Trustee believes is practicable. (Junior Subordinated Indenture, Section 307).

The principal, premium, if any, and interest on the Junior Subordinated Debentures at maturity will be payable when such Junior Subordinated Debentures are presented at the main corporate trust office of The Bank of New York Mellon, as paying agent, in New York City. NEE Capital and NEE may change the place of payment on the Junior Subordinated Debentures, appoint one or more additional paying agents, including NEE Capital, and remove any paying agent. (Junior Subordinated Indenture, Section 602).

Transfer and Exchange. Junior Subordinated Debentures may be transferred or exchanged at the main corporate trust office of The Bank of New York Mellon, as security registrar, in New York City. NEE Capital may

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change the place for transfer and exchange of the Junior Subordinated Debentures and may designate one or more additional places for that transfer and exchange.

There will be no service charge for any transfer or exchange of the Junior Subordinated Debentures. However, NEE Capital may require payment of any tax or other governmental charge in connection with any transfer or exchange of the Junior Subordinated Debentures.

NEE Capital will not be required to transfer or exchange any Junior Subordinated Debenture selected for redemption. Also, NEE Capital will not be required to transfer or exchange any Junior Subordinated Debenture during a period of 15 days before notice is to be given identifying the Junior Subordinated Debentures selected to be redeemed. (Junior Subordinated Indenture, Section 305).

Defeasance. NEE Capital and NEE may, at any time, elect to have all of their obligations discharged with respect to all or a portion of any Junior Subordinated Indenture Securities. To do so, NEE Capital or NEE must irrevocably deposit with the Junior Subordinated Indenture Trustee or any paying agent, in trust:

(1)    money in an amount that will be sufficient to pay all or that portion of the principal, premium, if any, and interest due and to become due on those Junior Subordinated Indenture Securities, on or prior to their maturity, or

(2)    in the case of a deposit made prior to the maturity of that series of Junior Subordinated Indenture Securities,

(a)    direct obligations of, or obligations unconditionally guaranteed by, the United States and entitled to the benefit of its full faith and credit that do not contain provisions permitting their redemption or other prepayment at the option of their issuer, and

(b)    certificates, depositary receipts or other instruments that evidence a direct ownership interest in those obligations or in any specific interest or principal payments due in respect of those obligations that do not contain provisions permitting their redemption or other prepayment at the option of their issuer,

the principal of and the interest on which, when due, without any regard to reinvestment of that principal or interest, will provide money that, together with any money deposited with or held by the Junior Subordinated Indenture Trustee, will be sufficient to pay all or that portion of the principal, premium, if any, and interest due and to become due on those Junior Subordinated Indenture Securities, on or prior to their maturity, or

(3)    a combination of  (1) and (2) that will be sufficient to pay all or that portion of the principal, premium, if any, and interest due and to become due on those Junior Subordinated Indenture Securities, on or prior to their maturity. (Junior Subordinated Indenture, Section 701).

Consolidation, Merger, and Sale of Assets. Under the Junior Subordinated Indenture, neither NEE Capital nor NEE may consolidate with or merge into any other entity or convey, transfer or lease its properties and assets substantially as an entirety to any entity, unless:

(1)    the entity formed by that consolidation, or the entity into which NEE Capital or NEE, as the case may be, is merged, or the entity that acquires or leases the properties and assets of NEE Capital or NEE, as the case may be, is an entity organized and existing under the laws of the United States, any state or the District of Columbia and that entity expressly assumes NEE Capital’s or NEE’s, as the case may be, obligations on all Junior Subordinated Indenture Securities and under the Junior Subordinated Indenture,

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(2)    immediately after giving effect to the transaction, no event of default under the Junior Subordinated Indenture and no event that, after notice or lapse of time or both, would become an event of default under the Junior Subordinated Indenture exists, and

(3)    NEE Capital or NEE, as the case may be, delivers an officer’s certificate and an opinion of counsel to the Junior Subordinated Indenture Trustee, as provided in the Junior Subordinated Indenture. (Junior Subordinated Indenture, Section 1101).

The Junior Subordinated Indenture does not prevent or restrict:

(a)    any consolidation or merger after the consummation of which NEE Capital or NEE, as the case may be, would be the surviving or resulting entity,

(b)    any consolidation of NEE Capital with NEE or any other entity all of the outstanding voting securities of which are owned, directly or indirectly, by NEE, or any merger of any such entity into any other of such entities, or any conveyance or other transfer, or lease, of properties or assets by any thereof to any other thereof,

(c)    any conveyance or other transfer, or lease, of any part of the properties or assets of NEE Capital or NEE which does not constitute the entirety, or substantially the entirety, thereof,

(d)    the approval by NEE Capital or NEE of or the consent by NEE Capital or NEE to any consolidation or merger to which any direct or indirect subsidiary or affiliate of NEE Capital or NEE, as the case requires, may be a party, or any conveyance, transfer or lease by any such subsidiary or affiliate of any or all of its properties or assets, or

(e)    any other transaction not contemplated by (1), (2) or (3) in the preceding paragraph. (Junior Subordinated Indenture, Section 1103).

Events of Default. Each of the following is an event of default under the Junior Subordinated Indenture with respect to the Junior Subordinated Indenture Securities of any series:

(1)    failure to pay interest on the Junior Subordinated Indenture Securities of that series within 30 days after it is due (provided, however, that a failure to pay interest during a valid optional deferral period will not constitute an event of default),

(2)    failure to pay principal or premium, if any, on the Junior Subordinated Indenture Securities of that series when it is due,

(3)    failure to perform, or breach of, any other covenant or warranty in the Junior Subordinated Indenture, other than a covenant or warranty that does not relate to that series of Junior Subordinated Indenture Securities, that continues for 90 days after (i) NEE Capital and NEE receive written notice of such failure to comply from the Junior Subordinated Indenture Trustee or (ii) NEE Capital, NEE and the Junior Subordinated Indenture Trustee receive written notice of such failure to comply from the registered owners of at least 33% in principal amount of the Junior Subordinated Indenture Securities of that series,

(4)    certain events of bankruptcy, insolvency or reorganization of NEE Capital or NEE, or

(5)    with certain exceptions, the Junior Subordinated Guarantee ceases to be effective, is found by a judicial proceeding to be unenforceable or invalid or is denied or disaffirmed by NEE.

In the case of an event of default listed in item (3) above, the Junior Subordinated Indenture Trustee may extend the grace period. In addition, if registered owners of a particular series have given a notice of default, then registered owners of at least the same percentage of Junior Subordinated Debentures of that series, together with the

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Junior Subordinated Indenture Trustee, may also extend the grace period. The grace period will be automatically extended if NEE Capital or NEE has initiated and is diligently pursuing corrective action in good faith. (Junior Subordinated Indenture, Section 801). An event of default with respect to the Junior Subordinated Indenture Securities of a particular series will not necessarily constitute an event of default with respect to Junior Subordinated Indenture Securities of any other series issued under the Junior Subordinated Indenture.

With respect to the Junior Subordinated Debentures,

•if any event of default, other than an event of default listed in item (3) above exists, and such event of default is not applicable to all outstanding securities issued under the Junior Subordinated Indenture, then either the Subordinated Indenture Trustee or the registered owners of at least 33% in aggregate principal amount of the Junior Subordinated Indenture Securities of each of the affected series may declare the principal of and accrued but unpaid interest on all the Junior Subordinated Indenture Securities of that series to be due and payable immediately; or

•if any event of default, other than an event of default listed in item (3) above, is applicable to all outstanding Junior Subordinated Indenture Securities, then only the Subordinated Indenture Trustee or the registered owners of at least 33% in aggregate principal amount of all outstanding Junior Subordinated Indenture Securities of all series, voting as one class, and not the registered owners of any one series, may make a declaration of acceleration.

Accordingly, if an event of default listed in item (3) above exists, the registered owners of the Junior Subordinated Debentures will not be entitled to vote to make a declaration of acceleration (and the Junior Subordinated Debentures will not be considered outstanding for the purpose of determining whether the required vote, described in the bullet points above, has been obtained), and the Subordinated Indenture Trustee will not have a right to make such declaration with respect to the Junior Subordinated Debentures.

The exception to the right to accelerate payment of the principal of and accrued but unpaid interest on Junior Subordinated Indenture Securities for an event of default listed in item (3) above does not apply to NEE Capital’s Series B Enhanced Junior Subordinated Debentures due 2066 and the Series C Junior Subordinated Debentures due 2067. Payment of Junior Subordinated Indenture Securities specified in the preceding sentence can be accelerated in the manner discussed above, upon the occurrence of each event of default listed above, and applicable to that series, including an event of default listed in item (3) above. See “ — Remedies” for a discussion of remedies available to the registered owners of the Junior Subordinated Indenture Securities (modified, as described above, for the Series L Junior Subordinated Debentures due September 29, 2057, the Series M Junior Subordinated Debentures due December 1, 2077, the Series N Junior Subordinated Debentures, the Series O Junior Subordinated Debentures due May 1, 2079 and the Series P Junior Subordinated Debentures due March 15, 2082).

Remedies. If an event of default applicable to the Junior Subordinated Indenture Securities of one or more series, but not applicable to all outstanding Junior Subordinated Indenture Securities, exists, then either (i) the Junior Subordinated Indenture Trustee or (ii) the registered owners of at least 33% in aggregate principal amount of the Junior Subordinated Indenture Securities of each of the affected series may declare the principal of and accrued but unpaid interest on all the Junior Subordinated Indenture Securities of that series to be due and payable immediately. (Junior Subordinated Indenture, Section 802). However, under the Junior Subordinated Indenture, some Junior Subordinated Indenture Securities may provide for a specified amount less than their entire principal amount to be due and payable upon that declaration. Such a Junior Subordinated Indenture Security is defined as a “Discount Security” in the Junior Subordinated Indenture.

A majority of the currently outstanding series of Junior Subordinated Indenture Securities contain an exception to the right to accelerate payment of the principal of and accrued but unpaid interest on Junior Subordinated Indenture Securities of those series for an event of default listed in item (3) under “Events of Default” above. With respect to such Junior Subordinated Indenture Securities, if an event of default listed in item (3) under “Events of Default” above exists, the registered owners of the Junior Subordinated Indenture Securities will not be entitled to vote to make a declaration of acceleration (and these Junior Subordinated Indenture Securities will not be considered outstanding for the purpose of determining whether the required vote, described above, has been

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obtained), and the Junior Subordinated Indenture Trustee will not have a right to make such declaration with respect to these Junior Subordinated Indenture Securities.

If an event of default is applicable to all outstanding Junior Subordinated Indenture Securities, then either (i) the Junior Subordinated Indenture Trustee or (ii) the registered owners of at least 33% in aggregate principal amount of all outstanding Junior Subordinated Indenture Securities of all series, voting as one class, and not the registered owners of any one series, may make a declaration of acceleration. However, the event of default giving rise to the declaration relating to any series of Junior Subordinated Indenture Securities will be automatically waived, and that declaration and its consequences will be automatically rescinded and annulled, if, at any time after that declaration and before a judgment or decree for payment of the money due has been obtained:

(1)    NEE Capital or NEE pays or deposits with the Junior Subordinated Indenture Trustee a sum sufficient to pay:

(a)    all overdue interest, if any, on all Junior Subordinated Indenture Securities of that series then outstanding,

(b)    the principal of and any premium on any Junior Subordinated Indenture Securities of that series that have become due for reasons other than that declaration, and interest that is then due,

(c)    interest on overdue interest for that series, and

(d)    all amounts then due to the Junior Subordinated Indenture Trustee under the Junior Subordinated Indenture, and

(2)    if, after application of money paid or deposited as described in item (1) above, Junior Subordinated Indenture Securities of that series would remain outstanding, any other event of default with respect to the Junior Subordinated Indenture Securities of that series has been cured or waived as provided in the Junior Subordinated Indenture. (Junior Subordinated Indenture, Section 802).

Other than its obligations and duties in case of an event of default under the Junior Subordinated Indenture, the Junior Subordinated Indenture Trustee is not obligated to exercise any of its rights or powers under the Junior Subordinated Indenture at the request or direction of any of the registered owners of the Junior Subordinated Indenture Securities, unless those registered owners offer reasonable indemnity to the Junior Subordinated Indenture Trustee. (Junior Subordinated Indenture, Section 903). If they provide this reasonable indemnity, the registered owners of a majority in principal amount of any series of Junior Subordinated Indenture Securities will have the right to direct the time, method and place of conducting any proceeding for any remedy available to the Junior Subordinated Indenture Trustee, or exercising any trust or power conferred on the Junior Subordinated Indenture Trustee, with respect to the Junior Subordinated Indenture Securities of that series. However, if an event of default under the Junior Subordinated Indenture relates to more than one series of Junior Subordinated Indenture Securities, only the registered owners of a majority in aggregate principal amount of all affected series of Junior Subordinated Indenture Securities, considered as one class, will have the right to make that direction. Also, the direction must not violate any law or the Junior Subordinated Indenture, and may not expose the Junior Subordinated Indenture Trustee to personal liability in circumstances where the indemnity would not, in the Junior Subordinated Indenture Trustee’s sole discretion, be adequate, and the Junior Subordinated Indenture Trustee may take any other action that it deems proper and not inconsistent with such direction. (Junior Subordinated Indenture, Section 812).

A registered owner of a Junior Subordinated Indenture Security has the right to institute a suit for the enforcement of payment of the principal of or premium, if any, or interest on that Junior Subordinated Indenture Security on or after the applicable due date specified in that Junior Subordinated Indenture Security. (Junior Subordinated Indenture, Section 808). No registered owner of Junior Subordinated Indenture Securities of any series will have any other right to institute any proceeding under the Junior Subordinated Indenture, or any other remedy under the Junior Subordinated Indenture, unless:

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(1)    that registered owner has previously given to the Junior Subordinated Indenture Trustee written notice of a continuing event of default with respect to the Junior Subordinated Indenture Securities of that series,

(2)    the registered owners of a majority in aggregate principal amount of the outstanding Junior Subordinated Indenture Securities of all series in respect of which an event of default under the Junior Subordinated Indenture exists, considered as one class, have made written request to the Junior Subordinated Indenture Trustee to institute that proceeding in its own name as trustee, and have offered reasonable indemnity to the Junior Subordinated Indenture Trustee against related costs, expenses and liabilities,

(3)    the Junior Subordinated Indenture Trustee for 60 days after its receipt of that notice, request and offer of indemnity has failed to institute any such proceeding, and

(4)    no direction inconsistent with that request was given to the Junior Subordinated Indenture Trustee during this 60 day period by the registered owners of a majority in aggregate principal amount of the outstanding Junior Subordinated Indenture Securities of all series in respect of which an event of default under the Junior Subordinated Indenture exists, considered as one class. (Junior Subordinated Indenture, Section 807).

Each of NEE Capital and NEE is required to deliver to the Junior Subordinated Indenture Trustee an annual statement as to its compliance with all conditions and covenants applicable to it under the Junior Subordinated Indenture. (Junior Subordinated Indenture, Section 606).

Modification and Waiver. Without the consent of any registered owner of Junior Subordinated Indenture Securities, NEE Capital, NEE and the Junior Subordinated Indenture Trustee may amend or supplement the Junior Subordinated Indenture for any of the following purposes:

(1)    to provide for the assumption by any permitted successor to NEE Capital or NEE of NEE Capital’s or NEE’s obligations under the Junior Subordinated Indenture and the Junior Subordinated Indenture Securities in the case of a merger or consolidation or a conveyance, transfer or lease of NEE Capital or NEE’s properties and assets substantially as an entirety,

(2)    to add covenants of NEE Capital or NEE or to surrender any right or power conferred upon NEE Capital or NEE by the Junior Subordinated Indenture,

(3)    to add any additional events of default,

(4)    to change, eliminate or add any provision of the Junior Subordinated Indenture, provided that if that change, elimination or addition will materially adversely affect the interests of the registered owners of Junior Subordinated Indenture Securities of any series or tranche, that change, elimination or addition will become effective with respect to that particular series or tranche only

(a)    when the required consent of the registered owners of Junior Subordinated Indenture Securities of that particular series or tranche has been obtained, or

(b)    when no Junior Subordinated Indenture Securities of that particular series or tranche remain outstanding under the Junior Subordinated Indenture,

(5)    to provide collateral security for all but not a part of the Junior Subordinated Indenture Securities,

(6)    to create the form or terms of Junior Subordinated Indenture Securities of any other series or tranche or any Junior Subordinated Guarantees,

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(7)    to provide for the authentication and delivery of bearer securities and the related coupons and for other matters relating to those bearer securities,

(8)    to accept the appointment of a successor Junior Subordinated Indenture Trustee or co-trustee with respect to the Junior Subordinated Indenture Securities of one or more series and to change any of the provisions of the Junior Subordinated Indenture as necessary to provide for the administration of the trusts under the Junior Subordinated Indenture by more than one trustee,

(9)    to add procedures to permit the use of a non-certificated system of registration for all, or any series or tranche of, the Junior Subordinated Indenture Securities,

(10)    to change any place where

(a)    the principal of and premium, if any, and interest on all, or any series or tranche of, Junior Subordinated Indenture Securities are payable,

(b)    all, or any series or tranche of, Junior Subordinated Indenture Securities may be surrendered for registration, transfer or exchange, and

(c)    notices and demands to or upon NEE Capital or NEE in respect of Junior Subordinated Indenture Securities and the Junior Subordinated Indenture may be served, or

(11)    to cure any ambiguity or inconsistency or to add or change any other provisions with respect to matters and questions arising under the Junior Subordinated Indenture, provided those changes or additions may not materially adversely affect the interests of the registered owners of Junior Subordinated Indenture Securities of any series or tranche. (Junior Subordinated Indenture, Section 1201).

The registered owners of a majority in aggregate principal amount of the Junior Subordinated Indenture Securities of all series then outstanding may waive compliance by NEE Capital or NEE with certain restrictive provisions of the Junior Subordinated Indenture. (Junior Subordinated Indenture, Section 607). The registered owners of a majority in principal amount of the outstanding Junior Subordinated Indenture Securities of any series may waive any past default under the Junior Subordinated Indenture with respect to that series, except a default in the payment of principal, premium, if any, or interest and a default with respect to certain restrictive covenants or provisions of the Junior Subordinated Indenture that cannot be modified or amended without the consent of the registered owner of each outstanding Junior Subordinated Indenture Security of that series affected. (Junior Subordinated Indenture, Section 813).

In addition to any amendments described above, if the Trust Indenture Act of 1939 is amended after the date of the Junior Subordinated Indenture in a way that requires changes to the Junior Subordinated Indenture or in a way that permits changes to, or the elimination of, provisions that were previously required by the Trust Indenture Act of 1939, the Junior Subordinated Indenture will be deemed to be amended to conform to that amendment of the Trust Indenture Act of 1939 or to make those changes, additions or eliminations. NEE Capital, NEE and the Junior Subordinated Indenture Trustee may, without the consent of any registered owners, enter into supplemental indentures to make that amendment. (Junior Subordinated Indenture, Section 1201).

Except for any amendments described above, the consent of the registered owners of a majority in aggregate principal amount of the Junior Subordinated Indenture Securities of all series then outstanding, considered as one class, is required for all other modifications to the Junior Subordinated Indenture. However, if less than all of the series of Junior Subordinated Indenture Securities outstanding are directly affected by a proposed supplemental indenture, then the consent only of the registered owners of a majority in aggregate principal amount of outstanding Junior Subordinated Indenture Securities of all directly affected series, considered as one class, is required. But, if NEE Capital issues any series of Junior Subordinated Indenture Securities in more than one tranche and if the proposed supplemental indenture directly affects the rights of the registered owners of Junior Subordinated Indenture Securities of less than all of those tranches, then the consent only of the registered owners of a majority in

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aggregate principal amount of the outstanding Junior Subordinated Indenture Securities of all directly affected tranches, considered as one class, will be required. However, none of those amendments or modifications may:

(1)    change the dates on which the principal of or interest (except as described above under “—Option to Defer Interest Payments”) on a Junior Subordinated Indenture Security is due without the consent of the registered owner of that Junior Subordinated Indenture Security,

(2)    reduce any Junior Subordinated Indenture Security’s principal amount or rate of interest (or the amount of any installment of that interest) or change the method of calculating that rate without the consent of the registered owner of that Junior Subordinated Indenture Security,

(3)    reduce any premium payable upon the redemption of a Junior Subordinated Indenture Security without the consent of the registered owner of that Junior Subordinated Indenture Security,

(4)    change the currency (or other property) in which a Junior Subordinated Indenture Security is payable without the consent of the registered owner of that Junior Subordinated Indenture Security,

(5)    impair the right to sue to enforce payments on any Junior Subordinated Indenture Security on or after the date that it states that the payment is due (or, in the case of redemption, on or after the redemption date) without the consent of the registered owner of that Junior Subordinated Indenture Security,

(6)    impair the right to receive payments under the Junior Subordinated Guarantee or to institute suit for enforcement of any such payment under the Junior Subordinated Guarantee,

(7)    reduce the percentage in principal amount of the outstanding Junior Subordinated Indenture Securities of any series or tranche whose owners must consent to an amendment, supplement or waiver without the consent of the registered owner of each outstanding Junior Subordinated Indenture Security of that particular series or tranche,

(8)    reduce the requirements for quorum or voting of any series or tranche without the consent of the registered owner of each outstanding Junior Subordinated Indenture Security of that particular series or tranche, or

(9)    modify certain of the provisions of the Junior Subordinated Indenture relating to supplemental indentures, waivers of certain covenants and waivers of past defaults with respect to the Junior Subordinated Indenture Securities of any series or tranche, without the consent of the registered owner of each outstanding Junior Subordinated Indenture Security affected by the modification.

A supplemental indenture that changes or eliminates any provision of the Junior Subordinated Indenture that has expressly been included only for the benefit of one or more particular series or tranches of Junior Subordinated Indenture Securities, or that modifies the rights of the registered owners of Junior Subordinated Indenture Securities of that particular series or tranche with respect to that provision, will not affect the rights under the Junior Subordinated Indenture of the registered owners of the Junior Subordinated Indenture Securities of any other series or tranche. (Junior Subordinated Indenture, Section 1202).

The Junior Subordinated Indenture provides that, in order to determine whether the registered owners of the required principal amount of the outstanding Junior Subordinated Indenture Securities have given any request, demand, authorization, direction, notice, consent or waiver under the Junior Subordinated Indenture, or whether a quorum is present at the meeting of the registered owners of Junior Subordinated Indenture Securities, Junior Subordinated Indenture Securities owned by NEE Capital, NEE or any other obligor upon the Junior Subordinated Indenture Securities or any affiliate of NEE Capital, NEE or of that other obligor (unless NEE Capital, NEE, that affiliate or that obligor owns all Junior Subordinated Indenture Securities outstanding under the Junior Subordinated Indenture, determined without regard to this provision), will be disregarded and deemed not to be outstanding. (Junior Subordinated Indenture, Section 101).

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If NEE Capital or NEE solicits any action under the Junior Subordinated Indenture from registered owners of Junior Subordinated Indenture Securities, each of NEE Capital or NEE may, at its option, fix in advance a record date for determining the registered owners of Junior Subordinated Indenture Securities entitled to take that action. However, neither NEE Capital nor NEE will be obligated to do so. If NEE Capital or NEE fixes such a record date, that action may be taken before or after that record date, but only the registered owners of record at the close of business on that record date will be deemed to be registered owners of Junior Subordinated Indenture Securities for the purposes of determining whether registered owners of the required proportion of the outstanding Junior Subordinated Indenture Securities have authorized that action. For these purposes, the outstanding Junior Subordinated Indenture Securities will be computed as of the record date. Any action of a registered owner of any Junior Subordinated Indenture Security under the Junior Subordinated Indenture will bind every future registered owner of that Junior Subordinated Indenture Security, or any Junior Subordinated Indenture Security replacing that Junior Subordinated Indenture Security, with respect to anything that the Junior Subordinated Indenture Trustee, NEE Capital or NEE do, fail to do, or allow to be done in reliance on that action, whether or not that action is noted upon that Junior Subordinated Indenture Security. (Junior Subordinated Indenture, Section 104).

Resignation and Removal of Junior Subordinated Indenture Trustee. The Junior Subordinated Indenture Trustee may resign at any time with respect to any series of Junior Subordinated Indenture Securities by giving written notice of its resignation to NEE Capital and NEE. Also, the registered owners of a majority in principal amount of the outstanding Junior Subordinated Indenture Securities of one or more series of Junior Subordinated Indenture Securities may remove the Junior Subordinated Indenture Trustee at any time with respect to the Junior Subordinated Indenture Securities of that series, by delivering an instrument evidencing this action to the Junior Subordinated Indenture Trustee, NEE Capital and NEE. The resignation or removal of the Junior Subordinated Indenture Trustee and the appointment of a successor trustee will not become effective until a successor trustee accepts its appointment.

Except with respect to a trustee under the Junior Subordinated Indenture appointed by the registered owners of Junior Subordinated Indenture Securities, the Junior Subordinated Indenture Trustee will be deemed to have resigned and the successor will be deemed to have been appointed as trustee in accordance with the Junior Subordinated Indenture if:

(1)    no event of default under the Junior Subordinated Indenture or event that, after notice or lapse of time, or both, would become an event of default under the Junior Subordinated Indenture exists, and

(2)    NEE Capital and NEE have delivered to the Junior Subordinated Indenture Trustee resolutions of their Boards of Directors appointing a successor trustee and that successor trustee has accepted that appointment in accordance with the terms of the Junior Subordinated Indenture. (Junior Subordinated Indenture, Section 910).

Notices. Notices to registered owners of Junior Subordinated Indenture Securities will be sent by mail to the addresses of those registered owners as they appear in the security register for those Junior Subordinated Indenture Securities. (Junior Subordinated Indenture, Section 106).

Title. NEE Capital, NEE, the Junior Subordinated Indenture Trustee, and any agent of NEE Capital, NEE or the Junior Subordinated Indenture Trustee, may treat the person in whose name a Junior Subordinated Indenture Security is registered as the absolute owner of that Junior Subordinated Indenture Security, whether or not that Junior Subordinated Indenture Security is overdue, for the purpose of making payments and for all other purposes, regardless of any notice to the contrary. (Junior Subordinated Indenture, Section 308).

Governing Law. The Junior Subordinated Indenture and the Junior Subordinated Indenture Securities are governed by, and will be construed in accordance with, the laws of the State of New York, without regard to conflict of laws principles thereunder, except to the extent that the law of any other jurisdiction is mandatorily applicable. (Junior Subordinated Indenture, Section 112).

Book-Entry Only Issuance. The Junior Subordinated Debentures will trade through DTC. The Junior Subordinated Debentures are represented by one or more global certificates and registered in the name of Cede & Co., DTC’s nominee. DTC or its nominee credited, on its book-entry registration and transfer system, the principal

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amount of the Junior Subordinated Debentures represented by such global certificates to the accounts of institutions that have an account with DTC or its participants.

Purchases of the Junior Subordinated Debentures within the DTC system must be made through participants, who will receive a credit for the Junior Subordinated Debentures on DTC’s records. The beneficial ownership interest of each purchaser will be recorded on the appropriate participant’s records. Beneficial owners will not receive written confirmation from DTC of their purchases, but beneficial owners should receive written confirmations of the transactions, as well as periodic statements of their holdings, from the participants through whom they purchased Junior Subordinated Debentures. Transfers of ownership in the Junior Subordinated Debentures are to be accomplished by entries made on the books of the participants acting on behalf of beneficial owners. Beneficial owners will not receive certificates for their Junior Subordinated Debentures, except if use of the book-entry system for the Junior Subordinated Debentures is discontinued.

To facilitate subsequent transfers, all Junior Subordinated Debentures deposited by participants with DTC are registered in the name of DTC’s nominee, Cede & Co. The deposit of the Junior Subordinated Debentures with DTC and their registration in the name of Cede & Co. effects no change in beneficial ownership. DTC has no knowledge of the actual beneficial owners of the Junior Subordinated Debentures. DTC’s records reflect only the identity of the participants to whose accounts such Junior Subordinated Debentures are credited. These participants may or may not be the beneficial owners. Participants will remain responsible for keeping account of their holdings on behalf of their customers.

Conveyance of notices and other communications by DTC to participants, and by participants to beneficial owners, will be governed by arrangements among them, subject to any statutory or regulatory requirements as may be in effect from time to time. Beneficial owners of Junior Subordinated Debentures may wish to take certain steps to augment transmission to them of notices of significant events with respect to the Junior Subordinated Debentures, such as redemptions, tenders, defaults and proposed amendments to the Subordinated Indenture. Beneficial owners of the Junior Subordinated Debentures may wish to ascertain that the nominee holding the Junior Subordinated Debentures has agreed to obtain and transmit notices to the beneficial owners.

Redemption notices will be sent to Cede & Co., as registered holder of the Junior Subordinated Debentures. If less than all of the Junior Subordinated Debentures are being redeemed, DTC’s practice is to determine by lot the amount of Junior Subordinated Debentures of each participant to be redeemed.

Neither DTC nor Cede & Co. will itself consent or vote with respect to Junior Subordinated Debentures, unless authorized by a participant in accordance with DTC’s procedures. Under its usual procedures, DTC would mail an omnibus proxy to NEE Capital as soon as possible after the record date. The omnibus proxy assigns the consenting or voting rights of Cede & Co. to those participants to whose accounts the Junior Subordinated Debentures are credited on the record date. NEE Capital and NEE believe that these arrangements will enable the beneficial owners to exercise rights equivalent in substance to the rights that can be directly exercised by a registered holder of the Junior Subordinated Debentures.

Payments of redemption proceeds, principal of, and interest on the Junior Subordinated Debentures will be made to Cede & Co., or such other nominee as may be requested by DTC. DTC’s practice is to credit participants’ accounts upon DTC’s receipt of funds and corresponding detail information from NEE Capital or its agent, on the payable date in accordance with their respective holdings shown on DTC’s records. Payments by participants to beneficial owners will be governed by standing instructions and customary practices. Payments will be the responsibility of participants and not of DTC, the Subordinated Indenture Trustee, NEE Capital or NEE, subject to any statutory or regulatory requirements as may be in effect from time to time. Payment of redemption proceeds, principal and interest to Cede & Co. (or such other nominee as may be requested by DTC) is the responsibility of NEE Capital. Disbursement of payments to participants is the responsibility of DTC, and disbursement of payments to the beneficial owners is the responsibility of participants.

Except as described below, a beneficial owner will not be entitled to receive physical delivery of the Junior Subordinated Debentures. Accordingly, each beneficial owner must rely on the procedures of DTC to exercise any rights under the Junior Subordinated Debentures.

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DTC may discontinue providing its services as securities depositary with respect to the Junior Subordinated Debentures at any time by giving reasonable notice to NEE Capital. In the event no successor securities depositary is obtained, certificates for the Junior Subordinated Debentures will be printed and delivered. NEE Capital and NEE may decide to replace DTC or any successor depositary. Additionally, subject to the procedures of DTC, NEE Capital and NEE may decide to discontinue use of the system of book-entry transfers through DTC (or a successor depositary) with respect to some or all of the Junior Subordinated Debentures. In that event, certificates for such Junior Subordinated Debentures will be printed and delivered. If certificates for Junior Subordinated Debentures are printed and delivered,

•the Junior Subordinated Debentures will be issued in fully registered form without coupons;

•a holder of certificated Junior Subordinated Debentures would be able to exchange those Junior Subordinated Debentures, without charge, for an equal aggregate principal amount of Junior Subordinated Debentures of the same series, having the same issue date and with identical terms and provisions; and

•a holder of certificated Junior Subordinated Debentures would be able to transfer those Junior Subordinated Debentures without cost to another holder, other than for applicable stamp taxes or other governmental charges.

Purchases of global securities under the DTC system must be made by or through direct participants, which will receive a credit for the global securities on DTC’s records. The ownership interest of each actual purchaser of each security (“Beneficial Owner”) is in turn to be recorded on the direct and indirect participants’ records. Beneficial Owners will not receive written confirmation from DTC of their purchase, but Beneficial Owners are expected to receive written confirmations providing details of the transaction, as well as periodic statements of their holdings, from the direct participant or indirect participant through which the Beneficial Owner entered into the transaction.

The information in this section concerning DTC and DTC’s book-entry system has been obtained from sources that NEE Capital and NEE believe to be reliable, but neither NEE Capital or NEE takes any responsibility for the accuracy of this information.

Agreement by Holders of Certain Tax Treatment. Each holder of the Junior Subordinated Debentures will, by accepting the Junior Subordinated Debentures or a beneficial interest therein, be deemed to have agreed that the holder intends that the Junior Subordinated Debentures constitute indebtedness and will treat the Junior Subordinated Debentures as indebtedness for all United States federal, state and local tax purposes.

IV.     INFORMATION CONCERNING THE TRUSTEE

NEE and its subsidiaries, including NEE Capital, and various of their affiliates maintain various banking and trust relationships with The Bank of New York Mellon and its affiliates. The Bank of New York Mellon acts as (i) indenture trustee, security registrar and paying agent under the indenture described under “Description of the NEE Capital Debentures” above, (ii) guarantee trustee under the guarantee agreement described under “Description of NEE Guarantee” above, (iii) purchase contract agent under the purchase contract agreements described under “Description of Description of Equity Units” above and (iv) Junior Subordinated Indenture Trustee, security registrar and paying agent under the Junior Subordinated Indenture described under “Description of the NEE Capital Junior Subordinated Debentures and NEE Junior Subordinated Guarantee” above.

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EX-4.B

Exhibit 4(b)

This instrument was prepared by:
Paul I. Cutler
Florida Power & Light Company
700 Universe Boulevard
Juno Beach, Florida 33408

______________________________________________________________________________

FLORIDA POWER & LIGHT COMPANY

to

DEUTSCHE BANK TRUST COMPANY AMERICAS

(formerly known as Bankers Trust Company)

As Trustee under Florida Power & Light
Company’s Mortgage and Deed of Trust,
Dated as of January 1, 1944

One Hundred Thirty-Third Supplemental Indenture

Relating to $1,200,000,000 Principal Amount
of First Mortgage Bonds, 2.875% Series
due December 4, 2051

Dated as of November 1, 2021

__________________________________________________________________

This Supplemental Indenture has been executed in several counterparts, all of which constitute but one and the same instrument. This Supplemental Indenture has been recorded in several counties and documentary stamp taxes as required by law in the amount of $4,200,000.00 and non-recurring intangible taxes as required by law in the amount of $129,728.66 are being paid on the Supplemental Indenture being recorded in the public records of Palm Beach County, Florida.

Note to Examiner: The new bonds being issued in connection with this Supplemental Indenture (“New Bonds”) are secured by real property and personal property located both within Florida and outside of Florida. The aggregate fair market value of the collateral exceeds the aggregate principal amount of (y) the New Bonds plus (z) the other outstanding bonds secured by the mortgage supplemented hereby and all previous supplemental indentures thereto. The intangible tax has been computed pursuant to Section 199.133(2), Florida Statutes, by (i) determining the percentage of the aggregate fair market value of the collateral constituting real property situated in Florida and by multiplying that percentage times the principal amount of the New Bonds (the result hereinafter defined as the “Tax Base”) and (ii) multiplying the tax rate times the Tax Base.

ONE HUNDRED THIRTY-THIRD SUPPLEMENTAL INDENTURE

INDENTURE, dated as of the 1st day of November, 2021, made and entered into by and between Florida Power & Light Company, a corporation of the State of Florida, whose post office address is 700 Universe Boulevard, Juno Beach, Florida 33408 (hereinafter sometimes called “FPL”), and Deutsche Bank Trust Company Americas (formerly known as Bankers Trust Company), a corporation of the State of New York, whose post office address is 60 Wall Street, 24th Floor, New York, New York 10005 (hereinafter called the “Trustee”), as the one hundred thirty-third supplemental indenture (hereinafter called the “One Hundred Thirty-Third Supplemental Indenture”) to the Mortgage and Deed of Trust, dated as of January 1, 1944 (hereinafter called the “Mortgage”), made and entered into by FPL, the Trustee and The Florida National Bank of Jacksonville, as Co-Trustee (now resigned), the Trustee now acting as the sole trustee under the Mortgage, which Mortgage was executed and delivered by FPL to secure the payment of bonds issued or to be issued under and in accordance with the provisions thereof, reference to which Mortgage is hereby made, this One Hundred Thirty-Third Supplemental Indenture being supplemental thereto;

Whereas, by an instrument, dated as of April 15, 2002, filed with the Banking Department of the State of New York, Bankers Trust Company effected a corporate name change pursuant to which, effective such date, it is known as Deutsche Bank Trust Company Americas; and

Whereas, FPL has transferred to New Hampshire Transmission, LLC, a Delaware limited liability company, all of FPL’s property located in the State of New Hampshire that previously was subject to the lien of the Mortgage, and the Trustee by instrument dated June 29, 2010 (the “Release”) released such property from the lien of the Mortgage, and released and discharged the supplemental indentures and mortgages recorded in the State of New Hampshire listed on Exhibit B to the Release; and

Whereas, on January 1, 2021, pursuant to the Agreement and Plan of Merger dated as of December 18, 2020 between Gulf Power Company, a corporation of the State of Florida (hereinafter called “Gulf Power”), and FPL, Gulf Power was merged into FPL (the “Merger”) with FPL as the surviving corporation; and

Whereas, in connection with the Merger, FPL has acquired certain real and personal property described in, and subjected to the Lien of the Mortgage by the One Hundred Thirty-Second Supplemental Indenture, dated as of January 1, 2021, which One Hundred Thirty-Second Supplemental Indenture has been duly recorded or filed in the States of Florida, Georgia and Mississippi; and

Whereas, Section 8 of the Mortgage provides that the form of each series of bonds (other than the first series) issued thereunder shall be established by Resolution of the Board of Directors of FPL and that the form of such series, as established by said Board of Directors, shall specify the descriptive title of the bonds and various other terms thereof, and may also contain such provisions not inconsistent with the provisions of the Mortgage as the Board of Directors may, in its discretion, cause to be inserted therein expressing or referring to the terms and conditions upon which such bonds are to be issued and/or secured under the Mortgage; and

    - 1 -

Whereas, Section 120 of the Mortgage provides, among other things, that any power, privilege or right expressly or impliedly reserved to or in any way conferred upon FPL by any provision of the Mortgage, whether such power, privilege or right is in any way restricted or is unrestricted, may be in whole or in part waived or surrendered or subjected to any restriction if at the time unrestricted or to additional restriction if already restricted, and FPL may enter into any further covenants, limitations or restrictions for the benefit of any one or more series of bonds issued thereunder, or FPL may cure any ambiguity contained therein, or in any supplemental indenture, or may establish the terms and provisions of any series of bonds other than said first series, by an instrument in writing executed and acknowledged by FPL in such manner as would be necessary to entitle a conveyance of real estate to be recorded in all of the states in which any property at the time subject to the Lien of the Mortgage shall be situated; and

Whereas, FPL now desires to create the series of bonds described in Article I hereof and to add to its covenants and agreements contained in the Mortgage certain other covenants and agreements to be observed by it and to alter and amend in certain respects the covenants and provisions contained in the Mortgage; and

Whereas, the execution and delivery by FPL of this One Hundred Thirty-Third Supplemental Indenture, and the terms of the bonds, hereinafter referred to in Article I, have been duly authorized by the Board of Directors of FPL by appropriate resolutions of said Board of Directors;

Now, Therefore, This Indenture Witnesseth: That FPL, in consideration of the premises and of One Dollar to it duly paid by the Trustee at or before the ensealing and delivery of these presents, the receipt whereof is hereby acknowledged, and in further evidence of assurance of the estate, title and rights of the Trustee and in order further to secure the payment of both the principal of and interest and premium, if any, on the bonds from time to time issued under the Mortgage, according to their tenor and effect, and the performance of all the provisions of the Mortgage (including any instruments supplemental thereto and any modification made as in the Mortgage provided) and of said bonds, hereby grants, bargains, sells, releases, conveys, assigns, transfers, mortgages, pledges, sets over and confirms (subject, however, to Excepted Encumbrances as defined in Section 6 of the Mortgage) unto Deutsche Bank Trust Company Americas, as Trustee under the Mortgage, and to its successor or successors in said trust, and to said Trustee and its successors and assigns forever, all property, real, personal and mixed, acquired by FPL after the date of the execution and delivery of the Mortgage (except any herein or in the Mortgage, as heretofore supplemented, expressly excepted), now owned (except any properties heretofore released pursuant to any provisions of the Mortgage and in the process of being sold or disposed of by FPL) or, subject to the provisions of Section 87 of the Mortgage, hereafter acquired by FPL and wheresoever situated, including (without in anywise limiting or impairing by the enumeration of the same the scope and intent of the foregoing) all lands, power sites, flowage rights, water rights, water locations, water appropriations, ditches, flumes, reservoirs, reservoir sites, canals, raceways, dams, dam sites, aqueducts, and all rights or means for appropriating, conveying, storing and supplying water; all rights of way and roads; all plants for the generation of electricity by steam, water and/or other power; all power houses, gas plants,

    - 2 -

street lighting systems, standards and other equipment incidental thereto, telephone, radio and television systems, air-conditioning systems and equipment incidental thereto, water works, water systems, steam heat and hot water plants, substations, lines, service and supply systems, bridges, culverts, tracks, ice or refrigeration plants and equipment, offices, buildings and other structures and the equipment thereof; all machinery, engines, boilers, dynamos, electric, gas and other machines, regulators, meters, transformers, generators, motors, electrical, gas and mechanical appliances, conduits, cables, water, steam heat, gas or other pipes, gas mains and pipes, service pipes, fittings, valves and connections, pole and transmission lines, wires, cables, tools, implements, apparatus, furniture, chattels, and choses in action; all municipal and other franchises, consents or permits; all lines for the transmission and distribution of electric current, gas, steam heat or water for any purpose including towers, poles, wires, cables, pipes, conduits, ducts and all apparatus for use in connection therewith; all real estate, lands, easements, servitudes, licenses, permits, franchises, privileges, rights of way and other rights in or relating to real estate or the occupancy of the same and (except as herein or in the Mortgage, as heretofore supplemented, expressly excepted) all the right, title and interest of FPL in and to all other property of any kind or nature appertaining to and/or used and/or occupied and/or enjoyed in connection with any property hereinbefore or in the Mortgage, as heretofore supplemented, described.

Together With all and singular the tenements, hereditaments and appurtenances belonging or in anywise appertaining to the aforesaid property or any part thereof, with the reversion and reversions, remainder and remainders and (subject to the provisions of Section 57 of the Mortgage) the tolls, rents, revenues, issues, earnings, income, products and profits thereof, and all the estate, right, title and interest and claim whatsoever, at law as well as in equity, which FPL now has or may hereinafter acquire in and to the aforesaid property and franchises and every part and parcel thereof.

It Is Hereby Agreed by FPL that, subject to the provisions of Section 87 of the Mortgage, all the property, rights, and franchises acquired by FPL after the date hereof (except any herein or in the Mortgage, as heretofore supplemented, expressly excepted) shall be and are as fully granted and conveyed hereby and as fully embraced within the Lien of the Mortgage, as if such property, rights and franchises were now owned by FPL and were specifically described herein and conveyed hereby.

Provided that the following are not and are not intended to be now or hereafter granted, bargained, sold, released, conveyed, assigned, transferred, mortgaged, pledged, set over or confirmed hereunder and are hereby expressly excepted from the Lien and operation of this One Hundred Thirty-Third Supplemental Indenture and from the Lien and operation of the Mortgage, as heretofore supplemented, viz: (1) cash, shares of stock, bonds, notes and other obligations and other securities not hereafter specifically pledged, paid, deposited, delivered or held under the Mortgage or covenanted so to be; (2) merchandise, equipment, materials or supplies held for the purpose of sale in the usual course of business and fuel (including Nuclear Fuel unless expressly subjected to the Lien and operation of the Mortgage by FPL in a future supplemental indenture), oil and similar materials and supplies consumable in the operation of any properties of FPL; rolling stock, buses, motor coaches, automobiles and other vehicles; (3) bills, notes and accounts receivable, and all contracts, leases and operating agreements not specifically pledged under the Mortgage or covenanted so to be; (4) the last day of the term of

    - 3 -

any lease or leasehold which may hereafter become subject to the Lien of the Mortgage; (5) electric energy, gas, ice, and other materials or products generated, manufactured, produced or purchased by FPL for sale, distribution or use in the ordinary course of its business; all timber, minerals, mineral rights and royalties; (6) FPL’s franchise to be a corporation; and (7) the properties already sold or in the process of being sold by FPL and heretofore released from the Mortgage and Deed of Trust, dated as of January 1, 1926, from Florida Power & Light Company to Bankers Trust Company and The Florida National Bank of Jacksonville, trustees, and specifically described in three separate releases executed by Bankers Trust Company and The Florida National Bank of Jacksonville, dated July 28, 1943, October 6, 1943 and December 11, 1943, which releases have heretofore been delivered by the said trustees to FPL and recorded by FPL among the Public Records of all Counties in which such properties are located; provided, however, that the property and rights expressly excepted from the Lien and operation of the Mortgage in the above subdivisions (2) and (3) shall (to the extent permitted by law) cease to be so excepted in the event and as of the date that the Trustee or a receiver or trustee shall enter upon and take possession of the Mortgaged and Pledged Property in the manner provided in Article XIII of the Mortgage by reason of the occurrence of a Default as defined in Section 65 thereof.

To Have And To Hold all such properties, real, personal and mixed, granted, bargained, sold, released, conveyed, assigned, transferred, mortgaged, pledged, set over or confirmed by FPL as aforesaid, or intended so to be, unto Deutsche Bank Trust Company Americas, the Trustee, and its successors and assigns forever.

In Trust Nevertheless, for the same purposes and upon the same terms, trusts and conditions and subject to and with the same provisos and covenants as are set forth in the Mortgage, as heretofore supplemented, this One Hundred Thirty-Third Supplemental Indenture being supplemental thereto.

And It Is Hereby Covenanted by FPL that all terms, conditions, provisos, covenants and provisions contained in the Mortgage shall affect and apply to the property hereinbefore described and conveyed and to the estate, rights, obligations and duties of FPL and the Trustee and the beneficiaries of the trust with respect to said property, and to the Trustee and its successors as Trustee of said property in the same manner and with the same effect as if said property had been owned by FPL at the time of the execution of the Mortgage, and had been specifically and at length described in and conveyed to said Trustee, by the Mortgage as a part of the property therein stated to be conveyed.

FPL further covenants and agrees to and with the Trustee and its successors in said trust under the Mortgage, as follows:

ARTICLE I
One Hundred Twenty-Eighth Series of Bonds

Section 1.(I) There shall be a series of bonds designated “2.875% Series due December 4, 2051”, herein sometimes referred to as the “One Hundred Twenty-Eighth Series”, each of which shall also bear the descriptive title First Mortgage Bond, and the form thereof, which shall be established by Resolution of the Board of Directors of FPL, shall contain suitable provisions with respect to the matters hereinafter in this Section specified. Bonds of the

    - 4 -

One Hundred Twenty-Eighth Series shall mature on December 4, 2051 and shall be issued as fully registered bonds in denominations of Two Thousand Dollars and, at the option of FPL, in integral multiples of One Thousand Dollars in excess thereof (the exercise of such option to be evidenced by the execution and delivery thereof); they shall bear interest at the rate of 2.875% per annum, payable semi-annually on June 4 and December 4 of each year (each an “Interest Payment Date”) commencing on June 4, 2022; the principal of and interest on each said bond to be payable at the office or agency of FPL in the Borough of Manhattan, The City of New York, in such coin or currency of the United States of America as at the time of payment is legal tender for public and private debts. Bonds of the One Hundred Twenty-Eighth Series shall be dated as in Section 10 of the Mortgage provided. The record date for payments of interest on any Interest Payment Date shall be the close of business on (1) the Business Day (as defined below) immediately preceding such Interest Payment Date so long as all of the bonds of the One Hundred Twenty-Eighth Series are held by a securities depository in book-entry only form or (2) the 15th calendar day immediately preceding such Interest Payment Date if any of the bonds of the One Hundred Twenty-Eighth Series are not held by a securities depository in book-entry only form. Interest on the bonds of the One Hundred Twenty-Eighth Series will accrue from and including November 18, 2021 to but excluding June 4, 2022 and, thereafter, from and including the last Interest Payment Date to which interest has been paid or duly provided for (and if no interest has been paid on the bonds of the One Hundred Twenty-Eighth Series, from November 18, 2021) to but excluding the next succeeding Interest Payment Date. No interest will accrue on a bond of the One Hundred Twenty-Eighth Series for the day on which such bond matures. The amount of interest payable for any period will be computed on the basis of a 360-day year consisting of twelve 30-day months. The amount of interest payable for any period shorter than a full semi-annual period for which interest is computed will be computed on the basis of the number of days in the period using 30-day calendar months. If any date on which interest, principal or premium, if any, is payable on the bonds of the One Hundred Twenty-Eighth Series falls on a day that is not a Business Day, then payment of the interest, principal or premium payable on that date will be made on the next succeeding day which is a Business Day, and without any interest or other payment in respect of such delay. A “Business Day” is any day that is not a Saturday, a Sunday, or a day on which banking institutions or trust companies in New York City are generally authorized or required by law or executive order to remain closed.

(II)Bonds of the One Hundred Twenty-Eighth Series shall be redeemable either at the option of FPL or pursuant to the requirements of the Mortgage (including, among other requirements, the application of cash delivered to or deposited with the Trustee pursuant to the provisions of Section 64 of the Mortgage or with proceeds of Released Property) in whole at any time, or in part from time to time, prior to maturity of the bonds of the One Hundred Twenty-Eighth Series, upon notice as provided in Section 52 of the Mortgage (the “Redemption Notice”), mailed at least thirty (30) days prior to the date fixed for redemption (the “Redemption Date”), at the applicable price (each a “Redemption Price”) described below. If FPL redeems all or any part of the bonds of the One Hundred Twenty-Eighth Series at any time prior to June 4, 2051 (the “Par Call Date”), the Redemption Price will equal the sum of (i) 100% of the principal amount thereof plus (ii) accrued and unpaid interest thereon, if any, to but excluding the Redemption Date, plus (iii) a premium, if any (the “Make-Whole Premium”). In no event will the Redemption Price be less than 100% of the principal amount of the bonds of

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the One Hundred Twenty-Eighth Series being redeemed plus accrued and unpaid interest thereon, if any, to but excluding the Redemption Date.

The amount of the Make-Whole Premium with respect to any bonds of the One Hundred Twenty-Eighth Series (or portion thereof) to be redeemed will be equal to the excess, if any, of:

(1)the sum of the present values, calculated as of the Redemption Date, of:

a.each interest payment that, but for such redemption, would have been payable on the bonds of the One Hundred Twenty-Eighth Series (or portion thereof) being redeemed on each Interest Payment Date occurring after the Redemption Date that would be payable if the bonds of the One Hundred Twenty-Eighth Series (or portion thereof) matured on the Par Call Date (excluding any interest accruing (i) from and including the last Interest Payment Date preceding the Redemption Date as of which all then-accrued interest was paid (ii) to but excluding the Redemption Date); and

b.the principal amount that, but for such redemption, would have been payable at the final maturity of the bonds of the One Hundred Twenty-Eighth Series (or portion thereof) being redeemed; over

(2)the principal amount of the bonds of the One Hundred Twenty-Eighth Series (or portion thereof) being redeemed.

The present values of interest and principal payments referred to in clause (1) above will be determined in accordance with generally accepted principles of financial analysis. Such present values will be calculated by discounting the amount of each payment of interest or principal from the date that each such payment would have been payable, but for the redemption, to but excluding the Redemption Date at a discount rate equal to the Treasury Yield (as defined below) plus 15 basis points.

If FPL redeems all or any part of the bonds of the One Hundred Twenty-Eighth Series at any time on or after the Par Call Date, the Redemption Price will be 100% of the principal amount thereof plus accrued and unpaid interest thereon, if any, to but excluding the Redemption Date.

FPL will appoint an independent investment banking institution of national standing to calculate the Make-Whole Premium when and as applicable; provided that if FPL fails to make such appointment at least thirty (30) days prior to the Redemption Date, or if the institution so appointed is unwilling or unable to make such calculation, such calculation will be made by Citigroup Global Markets Inc., Fifth Third Securities, Inc., RBC Capital Markets, LLC, Regions Securities LLC, U.S. Bancorp Investments, Inc. or Wells Fargo Securities, LLC, or if such firms are unwilling or unable to make such calculation, by an independent investment banking institution of national standing appointed by the Trustee in consultation with, and at the expense of, FPL (in any such case, an “Independent Investment Banker”).

    - 6 -

For purposes of determining the Make-Whole Premium, “Treasury Yield” means a rate of interest per annum equal to the weekly average yield to maturity of United States Treasury Notes that have a constant maturity that corresponds to the remaining term to maturity of the bonds of the One Hundred Twenty-Eighth Series to be redeemed (assuming for this purpose that the bonds of the One Hundred Twenty-Eighth Series mature on the Par Call Date), in each case calculated to the nearest 1/12th of a year (the “Remaining Term”). The Independent Investment Banker will determine the Treasury Yield as of the third Business Day immediately preceding the applicable Redemption Date.

The Independent Investment Banker will determine the weekly average yields of United States Treasury Notes by reference to the most recent statistical release published by the Federal Reserve Bank of New York and designated “H.15 Selected Interest Rates” or any successor release (the “H.15 Statistical Release”). If the H.15 Statistical Release sets forth a weekly average yield for United States Treasury Notes having a constant maturity that is the same as the Remaining Term, then the Treasury Yield will be equal to such weekly average yield. In all other cases, the Independent Investment Banker will calculate the Treasury Yield by interpolation, on a straight-line basis, between the weekly average yields on the United States Treasury Notes that have a constant maturity closest to and greater than the Remaining Term and the United States Treasury Notes that have a constant maturity closest to and less than the Remaining Term (in each case as set forth in the H.15 Statistical Release). The Independent Investment Banker will round any weekly average yields so calculated to the nearest 1/100th of 1%, and will round upward any figure of 1/200th of 1% or above. If weekly average yields for United States Treasury Notes are not available in the H.15 Statistical Release or otherwise, then the Independent Investment Banker will select comparable rates and calculate the Treasury Yield by reference to those rates.

(III)At the option of the registered owner, any bonds of the One Hundred Twenty-Eighth Series, upon surrender thereof for exchange at the office or agency of FPL in the Borough of Manhattan, The City of New York, together with a written instrument of transfer wherever required by FPL, duly executed by the registered owner or by his duly authorized attorney, shall (subject to the provisions of Section 12 of the Mortgage) be exchangeable for a like aggregate principal amount of bonds of the same series of other authorized denominations.

Bonds of the One Hundred Twenty-Eighth Series shall be transferable (subject to the provisions of Section 12 of the Mortgage) at the office or agency of FPL in the Borough of Manhattan, The City of New York.

Upon any exchange or transfer of bonds of the One Hundred Twenty-Eighth Series, FPL may make a charge therefor sufficient to reimburse it for any tax or taxes or other governmental charge, as provided in Section 12 of the Mortgage, but FPL hereby waives any right to make a charge in addition thereto for any exchange or transfer of bonds of the One Hundred Twenty-Eighth Series.

    - 7 -

ARTICLE II

Consent to Amendments of the Mortgage

Section 2.Each initial and future holder of bonds of the One Hundred Twenty-Eighth Series, by its acquisition of an interest in such bonds, irrevocably (a) consents to the amendments set forth in Article II of the One Hundred Twenty-Eighth Supplemental Indenture, dated as of June 15, 2018, without any other or further action by any holder of such bonds, and (b) designates the Trustee, and its successors, as its proxy with irrevocable instructions to vote and deliver written consents on behalf of such holder in favor of such amendments at any bondholder meeting, in lieu of any bondholder meeting, in any consent solicitation or otherwise.

ARTICLE III

Miscellaneous Provisions

Section 3. Subject to the amendments provided for in this One Hundred Thirty-Third Supplemental Indenture, the terms defined in the Mortgage, as heretofore supplemented, shall, for all purposes of this One Hundred Thirty-Third Supplemental Indenture, have the meanings specified in the Mortgage, as heretofore supplemented.

Section 4. The holders of bonds of the One Hundred Twenty-Eighth Series consent that FPL may, but shall not be obligated to, fix a record date for the purpose of determining the holders of bonds of the One Hundred Twenty-Eighth Series entitled to consent to any amendment, supplement or waiver. If a record date is fixed, those persons who were holders at such record date (or their duly designated proxies), and only those persons, shall be entitled to consent to such amendment, supplement or waiver or to revoke any consent previously given, whether or not such persons continue to be holders after such record date. No such consent shall be valid or effective for more than ninety (90) days after such record date.

Section 5. The Trustee hereby accepts the trust herein declared, provided, created or supplemented and agrees to perform the same upon the terms and conditions herein and in the Mortgage, as heretofore supplemented, set forth and upon the following terms and conditions:

The Trustee shall not be responsible in any manner whatsoever for or in respect of the validity or sufficiency of this One Hundred Thirty-Third Supplemental Indenture or for or in respect of the recitals contained herein, all of which recitals are made by FPL solely. In general, each and every term and condition contained in Article XVII of the Mortgage, as heretofore amended, shall apply to and form part of this One Hundred Thirty-Third Supplemental Indenture with the same force and effect as if the same were herein set forth in full with such omissions, variations and insertions, if any, as may be appropriate to make the same conform to the provisions of this One Hundred Thirty-Third Supplemental Indenture.

Section 6. Whenever in this One Hundred Thirty-Third Supplemental Indenture either of the parties hereto is named or referred to, this shall, subject to the provisions of Articles XVI and XVII of the Mortgage, as heretofore amended, be deemed to include the successors and assigns of such party, and all the covenants and agreements in this One Hundred Thirty-Third Supplemental Indenture contained by or on behalf of FPL, or by or on behalf of the Trustee, or

    - 8 -

either of them, shall, subject as aforesaid, bind and inure to the respective benefits of the respective successors and assigns of such parties, whether so expressed or not.

Section 7. Nothing in this One Hundred Thirty-Third Supplemental Indenture, expressed or implied, is intended, or shall be construed, to confer upon, or to give to, any person, firm or corporation, other than the parties hereto and the holders of the bonds and coupons Outstanding under the Mortgage, any right, remedy or claim under or by reason of this One Hundred Thirty-Third Supplemental Indenture or any covenant, condition, stipulation, promise or agreement hereof, and all the covenants, conditions, stipulations, promises and agreements in this One Hundred Thirty-Third Supplemental Indenture contained by or on behalf of FPL shall be for the sole and exclusive benefit of the parties hereto, and of the holders of the bonds and coupons Outstanding under the Mortgage.

Section 8. The Mortgage, as heretofore supplemented and amended and as supplemented hereby, is intended by the parties hereto, as to properties now or hereafter encumbered thereby and located within the States of Florida, Georgia and Mississippi, to operate and is to be construed as granting a lien only on such properties and not as a deed passing title thereto.

Section 9. This One Hundred Thirty-Third Supplemental Indenture shall be executed in several counterparts, each of which shall be an original and all of which shall constitute but one and the same instrument.

In Witness Whereof, FPL has caused its corporate name to be hereunto affixed, and this instrument to be signed and sealed by its President or one of its Vice Presidents, and its corporate seal to be attested by its Secretary or one of its Assistant Secretaries for and in its behalf, and Deutsche Bank Trust Company Americas has caused its corporate name to be hereunto affixed, and this instrument to be signed and sealed by one or more of its Vice Presidents or Assistant Vice Presidents, and its corporate seal to be attested by one of its Vice Presidents, Assistant Vice Presidents, one of its Assistant Secretaries or one of its Associates, all as of the day and year first above written.

    - 9 -

Florida Power & Light Company

By: ROBERT E. BARRETT, JR.

Robert E. Barrett, Jr.

Vice President, Finance

Attest:

SHARON SARTOR

Sharon Sartor

Assistant Secretary

Executed, sealed and delivered by

Florida Power & Light Company

in the presence of:

W. JAY FRAZIER

    W. Jay Frazier

ZACHARY CHOQUETTE

    Zachary Choquette

Deutsche Bank Trust Company Americas

    As Trustee

By: IRINA GOLOVASHCHUK

Irina Golovashchuk

Vice President

By: CHRIS NIESZ

Chris Niesz

Vice President

[CORPORATE SEAL]

Attest:

JEFFREY SCHOENFELD

Jeffrey Schoenfeld

Vice President

Executed, sealed and delivered by

Deutsche Bank Trust Company Americas

in the presence of:

AMRITA S. PESCHLER

Amrita S. Peschler

ROBERT S. PESCHLER

    Robert S. Peschler

State of Florida

County of Palm Beach    }    SS:

On the 15th day of November, in the year 2021 before me by means of physical presence personally came Robert E. Barrett, Jr., to me known, who, being by me duly sworn, did depose and say that he is the Vice President, Finance of Florida Power & Light Company, one of the corporations described in and which executed the above instrument; that he knows the seal of said corporation; that the seal affixed to said instrument is such corporate seal; that it was so affixed by order of the Board of Directors of said corporation, and that he signed his name thereto by like order.

I Hereby Certify, that on this 15th day of November, 2021, before me by means of physical presence personally appeared Robert E. Barrett, Jr. and Sharon Sartor, respectively, the Vice President, Finance and an Assistant Secretary of Florida Power & Light Company, a corporation under the laws of the State of Florida, to me known to be the persons described in and who executed the foregoing instrument and severally acknowledged the execution thereof to be their free act and deed as such officers, for the uses and purposes therein mentioned; and that they affixed thereto the official seal of said corporation, and that said instrument is the act and deed of said corporation.

Witness my signature and official seal at Juno Beach, in the County of Palm Beach, and State of Florida, the day and year last aforesaid.

CASSANDRA A KELLY

Notary Public – State of Florida

Notary Public State of Florida

Cassandra A Kelly

My Commission GG 221409

Expires 05/23/2022

State of New Jersey

County of Monmouth        }    SS:

On the 15th day of November in the year 2021, before me by means of physical presence personally came Irina Golovashchuk and Chris Niesz, to me known, who, being by me duly sworn, did depose and say that they are respectively a Vice President and a Vice President of Deutsche Bank Trust Company Americas, one of the corporations described in and which executed the above instrument; that they know the seal of said corporation; that the seal affixed to said instrument is such corporate seal; that it was so affixed by order of the Board of Directors of said corporation, and that they signed their names thereto by like order.

I Hereby Certify, that on this 15th day of November, 2021, before me by means of physical presence personally appeared Irina Golovashchuk, Chris Niesz and Jeffrey Schoenfeld, respectively, a Vice President, a Vice President and a Vice President of Deutsche Bank Trust Company Americas, a corporation under the laws of the State of New York, to me known to be the persons described in and who executed the foregoing instrument and severally acknowledged the execution thereof to be their free act and deed as such officers, for the uses and purposes therein mentioned; and that they affixed thereto the official seal of said corporation, and that said instrument is the act and deed of said corporation.

Witness my signature and official seal at Little Silver, in the County of Monmouth, and State of New Jersey, the day and year last aforesaid.

ROBERT S. PESCHLER

Notary Public – State of New Jersey

ROBERT S. PESCHLER

NOTARY PUBLIC OF NEW JERSEY

Comm. # 2427815

My Commission Expires 12/11/2022

EX-4.C

Exhibit 4(c)

This instrument was prepared by:
Paul I. Cutler
Florida Power & Light Company
700 Universe Boulevard
Juno Beach, Florida 33408

______________________________________________________________________________

FLORIDA POWER & LIGHT COMPANY

to

DEUTSCHE BANK TRUST COMPANY AMERICAS

(formerly known as Bankers Trust Company)

As Trustee under Florida Power & Light
Company’s Mortgage and Deed of Trust,
Dated as of January 1, 1944

One Hundred Thirty-Fourth Supplemental Indenture

Relating to $1,500,000,000 Principal Amount
of First Mortgage Bonds, 2.45% Series
due February 3, 2032

Dated as of January 1, 2022

__________________________________________________________________

This Supplemental Indenture has been executed in several counterparts, all of which constitute but one and the same instrument. This Supplemental Indenture has been recorded in several counties and documentary stamp taxes as required by law in the amount of $5,250,000.00 and non-recurring intangible taxes as required by law in the amount of $182,457.95 are being paid on the Supplemental Indenture being recorded in the public records of Palm Beach County, Florida.

Note to Examiner: The new bonds being issued in connection with this Supplemental Indenture (“New Bonds”) are secured by real property and personal property located both within Florida and outside of Florida. The aggregate fair market value of the collateral exceeds the aggregate principal amount of (y) the New Bonds plus (z) the other outstanding bonds secured by the mortgage supplemented hereby and all previous supplemental indentures thereto. The intangible tax has been computed pursuant to Section 199.133(2), Florida Statutes, by (i) determining the percentage of the aggregate fair market value of the collateral constituting real property situated in Florida and by multiplying that percentage times the principal amount of the New Bonds (the result hereinafter defined as the “Tax Base”) and (ii) multiplying the tax rate times the Tax Base.

ONE HUNDRED THIRTY-FOURTH SUPPLEMENTAL INDENTURE

INDENTURE, dated as of the 1st day of January, 2022, made and entered into by and between Florida Power & Light Company, a corporation of the State of Florida, whose post office address is 700 Universe Boulevard, Juno Beach, Florida 33408 (hereinafter sometimes called “FPL”), and Deutsche Bank Trust Company Americas (formerly known as Bankers Trust Company), a corporation of the State of New York, whose post office address is Deutsche Bank Trust Company Americas, Trust and Agency Services, 1 Columbus Circle, 17th Floor, New York, New York 10019 (hereinafter called the “Trustee”), as the one hundred thirty-fourth supplemental indenture (hereinafter called the “One Hundred Thirty-Fourth Supplemental Indenture”) to the Mortgage and Deed of Trust, dated as of January 1, 1944 (hereinafter called the “Mortgage”), made and entered into by FPL, the Trustee and The Florida National Bank of Jacksonville, as Co-Trustee (now resigned), the Trustee now acting as the sole trustee under the Mortgage, which Mortgage was executed and delivered by FPL to secure the payment of bonds issued or to be issued under and in accordance with the provisions thereof, reference to which Mortgage is hereby made, this One Hundred Thirty-Fourth Supplemental Indenture being supplemental thereto;

Whereas, by an instrument, dated as of April 15, 2002, filed with the Banking Department of the State of New York, Bankers Trust Company effected a corporate name change pursuant to which, effective such date, it is known as Deutsche Bank Trust Company Americas; and

Whereas, FPL has transferred to New Hampshire Transmission, LLC, a Delaware limited liability company, all of FPL’s property located in the State of New Hampshire that previously was subject to the lien of the Mortgage, and the Trustee by instrument dated June 29, 2010 (the “Release”) released such property from the lien of the Mortgage, and released and discharged the supplemental indentures and mortgages recorded in the State of New Hampshire listed on Exhibit B to the Release; and

Whereas, on January 1, 2021, pursuant to the Agreement and Plan of Merger dated as of December 18, 2020 between Gulf Power Company, a corporation of the State of Florida (hereinafter called “Gulf Power”), and FPL, Gulf Power was merged into FPL (the “Merger”) with FPL as the surviving corporation; and

Whereas, in connection with the Merger, FPL has acquired certain real and personal property described in, and subjected to the Lien of the Mortgage by the One Hundred Thirty-Second Supplemental Indenture, dated as of January 1, 2021, which One Hundred Thirty-Second Supplemental Indenture has been duly recorded or filed in the States of Florida, Georgia and Mississippi; and

Whereas, Section 8 of the Mortgage provides that the form of each series of bonds (other than the first series) issued thereunder shall be established by Resolution of the Board of Directors of FPL and that the form of such series, as established by said Board of Directors, shall specify the descriptive title of the bonds and various other terms thereof, and may also contain

    - 1 -

such provisions not inconsistent with the provisions of the Mortgage as the Board of Directors may, in its discretion, cause to be inserted therein expressing or referring to the terms and conditions upon which such bonds are to be issued and/or secured under the Mortgage; and

Whereas, Section 120 of the Mortgage provides, among other things, that any power, privilege or right expressly or impliedly reserved to or in any way conferred upon FPL by any provision of the Mortgage, whether such power, privilege or right is in any way restricted or is unrestricted, may be in whole or in part waived or surrendered or subjected to any restriction if at the time unrestricted or to additional restriction if already restricted, and FPL may enter into any further covenants, limitations or restrictions for the benefit of any one or more series of bonds issued thereunder, or FPL may cure any ambiguity contained therein, or in any supplemental indenture, or may establish the terms and provisions of any series of bonds other than said first series, by an instrument in writing executed and acknowledged by FPL in such manner as would be necessary to entitle a conveyance of real estate to be recorded in all of the states in which any property at the time subject to the Lien of the Mortgage shall be situated; and

Whereas, FPL now desires to create the series of bonds described in Article I hereof and to add to its covenants and agreements contained in the Mortgage certain other covenants and agreements to be observed by it and to alter and amend in certain respects the covenants and provisions contained in the Mortgage; and

Whereas, the execution and delivery by FPL of this One Hundred Thirty-Fourth Supplemental Indenture, and the terms of the bonds, hereinafter referred to in Article I, have been duly authorized by the Board of Directors of FPL by appropriate resolutions of said Board of Directors;

Now, Therefore, This Indenture Witnesseth: That FPL, in consideration of the premises and of One Dollar to it duly paid by the Trustee at or before the ensealing and delivery of these presents, the receipt whereof is hereby acknowledged, and in further evidence of assurance of the estate, title and rights of the Trustee and in order further to secure the payment of both the principal of and interest and premium, if any, on the bonds from time to time issued under the Mortgage, according to their tenor and effect, and the performance of all the provisions of the Mortgage (including any instruments supplemental thereto and any modification made as in the Mortgage provided) and of said bonds, hereby grants, bargains, sells, releases, conveys, assigns, transfers, mortgages, pledges, sets over and confirms (subject, however, to Excepted Encumbrances as defined in Section 6 of the Mortgage) unto Deutsche Bank Trust Company Americas, as Trustee under the Mortgage, and to its successor or successors in said trust, and to said Trustee and its successors and assigns forever, all property, real, personal and mixed, acquired by FPL after the date of the execution and delivery of the Mortgage (except any herein or in the Mortgage, as heretofore supplemented, expressly excepted), now owned (except any properties heretofore released pursuant to any provisions of the Mortgage and in the process of being sold or disposed of by FPL) or, subject to the provisions of Section 87 of the Mortgage, hereafter acquired by FPL and wheresoever situated, including (without in anywise limiting or impairing by the enumeration of the same the scope and intent of the foregoing) all lands, power sites, flowage rights, water rights, water locations, water appropriations, ditches, flumes, reservoirs, reservoir sites, canals, raceways, dams, dam sites, aqueducts, and all rights or means for appropriating, conveying, storing and supplying water; all rights of way and roads; all plants

    - 2 -

for the generation of electricity by steam, water and/or other power; all power houses, gas plants, street lighting systems, standards and other equipment incidental thereto, telephone, radio and television systems, air-conditioning systems and equipment incidental thereto, water works, water systems, steam heat and hot water plants, substations, lines, service and supply systems, bridges, culverts, tracks, ice or refrigeration plants and equipment, offices, buildings and other structures and the equipment thereof; all machinery, engines, boilers, dynamos, electric, gas and other machines, regulators, meters, transformers, generators, motors, electrical, gas and mechanical appliances, conduits, cables, water, steam heat, gas or other pipes, gas mains and pipes, service pipes, fittings, valves and connections, pole and transmission lines, wires, cables, tools, implements, apparatus, furniture, chattels, and choses in action; all municipal and other franchises, consents or permits; all lines for the transmission and distribution of electric current, gas, steam heat or water for any purpose including towers, poles, wires, cables, pipes, conduits, ducts and all apparatus for use in connection therewith; all real estate, lands, easements, servitudes, licenses, permits, franchises, privileges, rights of way and other rights in or relating to real estate or the occupancy of the same and (except as herein or in the Mortgage, as heretofore supplemented, expressly excepted) all the right, title and interest of FPL in and to all other property of any kind or nature appertaining to and/or used and/or occupied and/or enjoyed in connection with any property hereinbefore or in the Mortgage, as heretofore supplemented, described.

Together With all and singular the tenements, hereditaments and appurtenances belonging or in anywise appertaining to the aforesaid property or any part thereof, with the reversion and reversions, remainder and remainders and (subject to the provisions of Section 57 of the Mortgage) the tolls, rents, revenues, issues, earnings, income, products and profits thereof, and all the estate, right, title and interest and claim whatsoever, at law as well as in equity, which FPL now has or may hereinafter acquire in and to the aforesaid property and franchises and every part and parcel thereof.

It Is Hereby Agreed by FPL that, subject to the provisions of Section 87 of the Mortgage, all the property, rights, and franchises acquired by FPL after the date hereof (except any herein or in the Mortgage, as heretofore supplemented, expressly excepted) shall be and are as fully granted and conveyed hereby and as fully embraced within the Lien of the Mortgage, as if such property, rights and franchises were now owned by FPL and were specifically described herein and conveyed hereby.

Provided that the following are not and are not intended to be now or hereafter granted, bargained, sold, released, conveyed, assigned, transferred, mortgaged, pledged, set over or confirmed hereunder and are hereby expressly excepted from the Lien and operation of this One Hundred Thirty-Fourth Supplemental Indenture and from the Lien and operation of the Mortgage, as heretofore supplemented, viz: (1) cash, shares of stock, bonds, notes and other obligations and other securities not hereafter specifically pledged, paid, deposited, delivered or held under the Mortgage or covenanted so to be; (2) merchandise, equipment, materials or supplies held for the purpose of sale in the usual course of business and fuel (including Nuclear Fuel unless expressly subjected to the Lien and operation of the Mortgage by FPL in a future supplemental indenture), oil and similar materials and supplies consumable in the operation of any properties of FPL; rolling stock, buses, motor coaches, automobiles and other vehicles; (3) bills, notes and accounts receivable, and all contracts, leases and operating agreements not

    - 3 -

specifically pledged under the Mortgage or covenanted so to be; (4) the last day of the term of any lease or leasehold which may hereafter become subject to the Lien of the Mortgage; (5) electric energy, gas, ice, and other materials or products generated, manufactured, produced or purchased by FPL for sale, distribution or use in the ordinary course of its business; all timber, minerals, mineral rights and royalties; (6) FPL’s franchise to be a corporation; and (7) the properties already sold or in the process of being sold by FPL and heretofore released from the Mortgage and Deed of Trust, dated as of January 1, 1926, from Florida Power & Light Company to Bankers Trust Company and The Florida National Bank of Jacksonville, trustees, and specifically described in three separate releases executed by Bankers Trust Company and The Florida National Bank of Jacksonville, dated July 28, 1943, October 6, 1943 and December 11, 1943, which releases have heretofore been delivered by the said trustees to FPL and recorded by FPL among the Public Records of all Counties in which such properties are located; provided, however, that the property and rights expressly excepted from the Lien and operation of the Mortgage in the above subdivisions (2) and (3) shall (to the extent permitted by law) cease to be so excepted in the event and as of the date that the Trustee or a receiver or trustee shall enter upon and take possession of the Mortgaged and Pledged Property in the manner provided in Article XIII of the Mortgage by reason of the occurrence of a Default as defined in Section 65 thereof.

To Have And To Hold all such properties, real, personal and mixed, granted, bargained, sold, released, conveyed, assigned, transferred, mortgaged, pledged, set over or confirmed by FPL as aforesaid, or intended so to be, unto Deutsche Bank Trust Company Americas, the Trustee, and its successors and assigns forever.

In Trust Nevertheless, for the same purposes and upon the same terms, trusts and conditions and subject to and with the same provisos and covenants as are set forth in the Mortgage, as heretofore supplemented, this One Hundred Thirty-Fourth Supplemental Indenture being supplemental thereto.

And It Is Hereby Covenanted by FPL that all terms, conditions, provisos, covenants and provisions contained in the Mortgage shall affect and apply to the property hereinbefore described and conveyed and to the estate, rights, obligations and duties of FPL and the Trustee and the beneficiaries of the trust with respect to said property, and to the Trustee and its successors as Trustee of said property in the same manner and with the same effect as if said property had been owned by FPL at the time of the execution of the Mortgage, and had been specifically and at length described in and conveyed to said Trustee, by the Mortgage as a part of the property therein stated to be conveyed.

FPL further covenants and agrees to and with the Trustee and its successors in said trust under the Mortgage, as follows:

ARTICLE I
One Hundred Twenty-Ninth Series of Bonds

Section 1.(I) There shall be a series of bonds designated “2.45% Series due February 3, 2032”, herein sometimes referred to as the “One Hundred Twenty-Ninth”, each of which shall also bear the descriptive title First Mortgage Bond, and the form thereof, which shall

    - 4 -

be established by Resolution of the Board of Directors of FPL, shall contain suitable provisions with respect to the matters hereinafter in this Section specified. Bonds of the One Hundred Twenty-Ninth Series shall mature on February 3, 2032 and shall be issued as fully registered bonds in denominations of Two Thousand Dollars and, at the option of FPL, in integral multiples of One Thousand Dollars in excess thereof (the exercise of such option to be evidenced by the execution and delivery thereof); they shall bear interest at the rate of 2.45% per annum, payable semi-annually on February 3 and August 3 of each year (each an “Interest Payment Date”) commencing on August 3, 2022; the principal of and interest on each said bond to be payable at the office or agency of FPL in the Borough of Manhattan, The City of New York, in such coin or currency of the United States of America as at the time of payment is legal tender for public and private debts. Bonds of the One Hundred Twenty-Ninth Series shall be dated as in Section 10 of the Mortgage provided. The record date for payments of interest on any Interest Payment Date shall be the close of business on (1) the Business Day (as defined below) immediately preceding such Interest Payment Date so long as all of the bonds of the One Hundred Twenty-Ninth Series are held by a securities depository in book-entry only form or (2) the 15th calendar day immediately preceding such Interest Payment Date if any of the bonds of the One Hundred Twenty-Ninth Series are not held by a securities depository in book-entry only form. Interest on the bonds of the One Hundred Twenty-Ninth Series will accrue from and including January 14, 2022 to but excluding August 3, 2022 and, thereafter, from and including the last Interest Payment Date to which interest has been paid or duly provided for (and if no interest has been paid on the bonds of the One Hundred Twenty-Ninth Series, from January 14, 2022) to but excluding the next succeeding Interest Payment Date. No interest will accrue on a bond of the One Hundred Twenty-Ninth Series for the day on which such bond matures. The amount of interest payable for any period will be computed on the basis of a 360-day year consisting of twelve 30-day months. The amount of interest payable for any period shorter than a full semi-annual period for which interest is computed will be computed on the basis of the number of days in the period using 30-day calendar months. If any date on which interest, principal or premium, if any, is payable on the bonds of the One Hundred Twenty-Ninth Series falls on a day that is not a Business Day, then payment of the interest, principal or premium payable on that date will be made on the next succeeding day which is a Business Day, and without any interest or other payment in respect of such delay. A “Business Day” is any day that is not a Saturday, a Sunday, or a day on which banking institutions or trust companies in New York City are generally authorized or required by law or executive order to remain closed.

(II)Bonds of the One Hundred Twenty-Ninth Series shall be redeemable either at the option of FPL or pursuant to the requirements of the Mortgage (including, among other requirements, the application of cash delivered to or deposited with the Trustee pursuant to the provisions of Section 64 of the Mortgage or with proceeds of Released Property) in whole at any time, or in part from time to time, prior to maturity of the bonds of the One Hundred Twenty-Ninth Series, upon notice as provided in Section 52 of the Mortgage (the “Redemption Notice”), which notice will be given as required by the Mortgage, as hereto and hereafter supplemented and amended, prior to the date fixed for redemption (the “Redemption Date”), at the price (each a “Redemption Price”) described below.

Prior to November 3, 2031 (three months prior to the maturity date of the bonds of the One Hundred Twenty-Ninth Series) (the “Par Call Date”), FPL may redeem the bonds of the One Hundred Twenty-Ninth Series at its option, in whole or in part, at any time and from time to

    - 5 -

time, at a Redemption Price (expressed as a percentage of principal amount and rounded to three decimal places) equal to the greater of:

(1)(a) the sum of the present values of the remaining scheduled payments of principal and interest thereon discounted to the Redemption Date (assuming the bonds of the One Hundred Twenty-Ninth Series matured on the Par Call Date) on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate (as defined below) plus 15 basis points less (b) interest accrued to the Redemption Date, and

(2)100% of the principal amount of the bonds of the One Hundred Twenty-Ninth Series to be redeemed,

plus, in either case, accrued and unpaid interest thereon to but excluding the Redemption Date.

On or after the Par Call Date, FPL may redeem the bonds of the One Hundred Twenty-Ninth Series, in whole or in part, at any time and from time to time, at a Redemption Price equal to 100% of the principal amount of the bonds of the One Hundred Twenty-Ninth Series being redeemed plus accrued and unpaid interest thereon to but excluding the Redemption Date.

“Treasury Rate” means, with respect to any Redemption Date, the yield determined by FPL in accordance with the following two paragraphs.

The Treasury Rate shall be determined by FPL after 4:15 p.m., New York City time (or after such time as yields on U.S. government securities are posted daily by the Board of Governors of the Federal Reserve System), on the third Business Day preceding the Redemption Date based upon the yield or yields for the most recent day that appear after such time on such day in the most recent statistical release published by the Board of Governors of the Federal Reserve System designated as “Selected Interest Rates (Daily) - H.15” (or any successor designation or publication) (“H.15”) under the caption “U.S. government securities–Treasury constant maturities–Nominal” (or any successor caption or heading). In determining the Treasury Rate, FPL shall select, as applicable:

(1)the yield for the Treasury constant maturity on H.15 exactly equal to the period from the Redemption Date to the Par Call Date (the “Remaining Life”); or

(2)if there is no such Treasury constant maturity on H.15 exactly equal to the Remaining Life, the two yields—one yield corresponding to the Treasury constant maturity on H.15 immediately shorter than and one yield corresponding to the Treasury constant maturity on H.15 immediately longer than the Remaining Life—and shall interpolate to the Par Call Date on a straight-line basis (using the actual number of days) using such yields and rounding the result to three decimal places; or

(3)if there is no such Treasury constant maturity on H.15 shorter than or longer than the Remaining Life, the yield for the single Treasury constant maturity on H.15 closest to the Remaining Life.

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For purposes of this paragraph, the applicable Treasury constant maturity or maturities on H.15 shall be deemed to have a maturity date equal to the relevant number of months or years, as applicable, of such Treasury constant maturity from the Redemption Date.

If on the third Business Day preceding the Redemption Date H.15 or any successor designation or publication is no longer published, FPL shall calculate the Treasury Rate based on the rate per annum equal to the semi-annual equivalent yield to maturity at 11:00 a.m., New York City time, on the second Business Day preceding such Redemption Date of the United States Treasury security maturing on, or with a maturity that is closest to, the Par Call Date, as applicable. If there is no United States Treasury security maturing on the Par Call Date but there are two or more United States Treasury securities with a maturity date equally distant from the Par Call Date, one with a maturity date preceding the Par Call Date and one with a maturity date following the Par Call Date, FPL shall select the United States Treasury security with a maturity date preceding the Par Call Date. If there are two or more United States Treasury securities maturing on the Par Call Date or two or more United States Treasury securities meeting the criteria of the preceding sentence, FPL shall select from among these two or more United States Treasury securities the United States Treasury security that is trading closest to par based upon the average of the bid and asked prices for such United States Treasury securities at 11:00 a.m., New York City time. In determining the Treasury Rate in accordance with the terms of this paragraph, the semi-annual yield to maturity of the applicable United States Treasury security shall be based upon the average of the bid and asked prices (expressed as a percentage of principal amount) at 11:00 a.m., New York City time, of such United States Treasury security, and rounded to three decimal places.

FPL’s actions and determinations in determining the Redemption Price shall be conclusive and binding for all purposes, absent manifest error.

The Trustee shall have no duty to determine, or to verify FPL’s calculations of, the Redemption Price.

(III)At the option of the registered owner, any bonds of the One Hundred Twenty-Ninth Series, upon surrender thereof for exchange at the office or agency of FPL in the Borough of Manhattan, The City of New York, together with a written instrument of transfer wherever required by FPL, duly executed by the registered owner or by his duly authorized attorney, shall (subject to the provisions of Section 12 of the Mortgage) be exchangeable for a like aggregate principal amount of bonds of the same series of other authorized denominations.

Bonds of the One Hundred Twenty-Ninth Series shall be transferable (subject to the provisions of Section 12 of the Mortgage) at the office or agency of FPL in the Borough of Manhattan, The City of New York.

Upon any exchange or transfer of bonds of the One Hundred Twenty-Ninth Series, FPL may make a charge therefor sufficient to reimburse it for any tax or taxes or other governmental charge, as provided in Section 12 of the Mortgage, but FPL hereby waives any right to make a charge in addition thereto for any exchange or transfer of bonds of the One Hundred Twenty-Ninth Series.

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ARTICLE II

Reservation of Right to Amend the Mortgage

Section 2.FPL reserves the right, without any vote, consent or other action by the holders of bonds of any series created after the date of this One Hundred Thirty-Fourth Supplemental Indenture, to amend the Mortgage, as hereby amended, to amend the fifth paragraph of Subsection (B) of Section 52 of the Mortgage to read substantially as follows:

Notice of intention to redeem to the registered owner of any bond registered as to principal and interest or as to principal only which is to be redeemed in whole or part shall be mailed by or on behalf of the Company, not less than ten (10) days before the date fixed for redemption, to the registered owner at such registered owner’s last address appearing upon the registry books.

ARTICLE III

Consent to Amendments of the Mortgage

Section 3.Each initial and future holder of bonds of the One Hundred Twenty-Ninth Series, by its acquisition of an interest in such bonds, irrevocably (a) consents to the amendments set forth in Article II of the One Hundred Twenty-Eighth Supplemental Indenture, dated as of June 15, 2018, without any other or further action by any holder of such bonds, and (b) designates the Trustee, and its successors, as its proxy with irrevocable instructions to vote and deliver written consents on behalf of such holder in favor of such amendments at any bondholder meeting, in lieu of any bondholder meeting, in any consent solicitation or otherwise.

ARTICLE IV

Miscellaneous Provisions

Section 4. Subject to the amendments provided for in this One Hundred Thirty-Fourth Supplemental Indenture, the terms defined in the Mortgage, as heretofore supplemented, shall, for all purposes of this One Hundred Thirty-Fourth Supplemental Indenture, have the meanings specified in the Mortgage, as heretofore supplemented.

Section 5. The holders of bonds of the One Hundred Twenty-Ninth Series consent that FPL may, but shall not be obligated to, fix a record date for the purpose of determining the holders of bonds of the One Hundred Twenty-Ninth Series entitled to consent to any amendment, supplement or waiver. If a record date is fixed, those persons who were holders at such record date (or their duly designated proxies), and only those persons, shall be entitled to consent to such amendment, supplement or waiver or to revoke any consent previously given, whether or not such persons continue to be holders after such record date. No such consent shall be valid or effective for more than ninety (90) days after such record date.

Section 6. The Trustee hereby accepts the trust herein declared, provided, created or supplemented and agrees to perform the same upon the terms and conditions herein and in the Mortgage, as heretofore supplemented, set forth and upon the following terms and conditions:

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The Trustee shall not be responsible in any manner whatsoever for or in respect of the validity or sufficiency of this One Hundred Thirty-Fourth Supplemental Indenture or for or in respect of the recitals contained herein, all of which recitals are made by FPL solely. In general, each and every term and condition contained in Article XVII of the Mortgage, as heretofore amended, shall apply to and form part of this One Hundred Thirty-Fourth Supplemental Indenture with the same force and effect as if the same were herein set forth in full with such omissions, variations and insertions, if any, as may be appropriate to make the same conform to the provisions of this One Hundred Thirty-Fourth Supplemental Indenture.

Section 7. Whenever in this One Hundred Thirty-Fourth Supplemental Indenture either of the parties hereto is named or referred to, this shall, subject to the provisions of Articles XVI and XVII of the Mortgage, as heretofore amended, be deemed to include the successors and assigns of such party, and all the covenants and agreements in this One Hundred Thirty-Fourth Supplemental Indenture contained by or on behalf of FPL, or by or on behalf of the Trustee, or either of them, shall, subject as aforesaid, bind and inure to the respective benefits of the respective successors and assigns of such parties, whether so expressed or not.

Section 8. Nothing in this One Hundred Thirty-Fourth Supplemental Indenture, expressed or implied, is intended, or shall be construed, to confer upon, or to give to, any person, firm or corporation, other than the parties hereto and the holders of the bonds and coupons Outstanding under the Mortgage, any right, remedy or claim under or by reason of this One Hundred Thirty-Fourth Supplemental Indenture or any covenant, condition, stipulation, promise or agreement hereof, and all the covenants, conditions, stipulations, promises and agreements in this One Hundred Thirty-Fourth Supplemental Indenture contained by or on behalf of FPL shall be for the sole and exclusive benefit of the parties hereto, and of the holders of the bonds and coupons Outstanding under the Mortgage.

Section 9. The Mortgage, as heretofore supplemented and amended and as supplemented hereby, is intended by the parties hereto, as to properties now or hereafter encumbered thereby and located within the States of Florida, Georgia and Mississippi, to operate and is to be construed as granting a lien only on such properties and not as a deed passing title thereto.

Section 10. This One Hundred Thirty-Fourth Supplemental Indenture shall be executed in several counterparts, each of which shall be an original and all of which shall constitute but one and the same instrument.

In Witness Whereof, FPL has caused its corporate name to be hereunto affixed, and this instrument to be signed and sealed by its President or one of its Vice Presidents, and its corporate seal to be attested by its Secretary or one of its Assistant Secretaries for and in its behalf, and Deutsche Bank Trust Company Americas has caused its corporate name to be hereunto affixed, and this instrument to be signed and sealed by one or more of its Vice Presidents or Assistant Vice Presidents, and its corporate seal to be attested by one of its Vice Presidents, Assistant Vice Presidents, one of its Assistant Secretaries or one of its Associates, all as of the day and year first above written.

    - 9 -

Florida Power & Light Company

By: BRUCE GOLDSTEIN

Bruce Goldstein

Vice President and Chief Tax Officer

Attest:

SHARON SARTOR

Sharon Sartor

Assistant Secretary

Executed, sealed and delivered by

Florida Power & Light Company

in the presence of:

ZACHARY CHOQUETTE

    Zachary Choquette

DAN TARVER

    Dan Tarver

Deutsche Bank Trust Company Americas

    As Trustee

By: IRINA GOLOVASHCHUK

Irina Golovashchuk

Vice President

By: CHRIS NIESZ

Chris Niesz

Vice President

[CORPORATE SEAL]

Attest:

JEFFREY SCHOENFELD

Jeffrey Schoenfeld

Vice President

Executed, sealed and delivered by

Deutsche Bank Trust Company Americas

in the presence of:

ROBERT S. PESCHLER

Robert S. Peschler

AMRITA S. PESCHLER

    Amrita S. Peschler

State of Florida

County of Palm Beach    }    SS:

On the 11th day of January, in the year 2022 before me by means of physical presence came Bruce Goldstein, personally known to me, who, being by me duly sworn, did depose and say that he is the Vice President and Chief Tax Officer of Florida Power & Light Company, one of the corporations described in and which executed the above instrument; that he knows the seal of said corporation; that the seal affixed to said instrument is such corporate seal; that it was so affixed by order of the Board of Directors of said corporation, and that he signed his name thereto by like order.

I Hereby Certify, that on this 11th day of January, 2022, before me by means of physical presence appeared Bruce Goldstein and Sharon Sartor, respectively, the Vice President and Chief Tax Officer and an Assistant Secretary of Florida Power & Light Company, a corporation under the laws of the State of Florida, to me personally known to be the persons described in and who executed the foregoing instrument and severally acknowledged the execution thereof to be their free act and deed as such officers, for the uses and purposes therein mentioned; and that they affixed thereto the official seal of said corporation, and that said instrument is the act and deed of said corporation.

Witness my signature and official seal at Juno Beach, in the County of Palm Beach, and State of Florida, the day and year last aforesaid.

CASSANDRA A KELLY

Notary Public – State of Florida

Notary Public State of Florida

Cassandra A Kelly

My Commission GG 221409

Expires 05/23/2022

State of New Jersey

County of Monmouth        }    SS:

On the 12th day of January in the year 2022, before me by means of physical presence came Irina Golovashchuk and Chris Niesz, personally known to me, who, being by me duly sworn, did depose and say that they are respectively a Vice President and a Vice President of Deutsche Bank Trust Company Americas, one of the corporations described in and which executed the above instrument; that they know the seal of said corporation; that the seal affixed to said instrument is such corporate seal; that it was so affixed by order of the Board of Directors of said corporation, and that they signed their names thereto by like order.

I Hereby Certify, that on this 12th day of January, 2022, before me by means of physical presence appeared Irina Golovashchuk, Chris Niesz and Jeffrey Schoenfeld, respectively, a Vice President, a Vice President and a Vice President of Deutsche Bank Trust Company Americas, a corporation under the laws of the State of New York, personally known to me to be the persons described in and who executed the foregoing instrument and severally acknowledged the execution thereof to be their free act and deed as such officers, for the uses and purposes therein mentioned; and that they affixed thereto the official seal of said corporation, and that said instrument is the act and deed of said corporation.

Witness my signature and official seal at Little Silver, in the County of Monmouth, and State of New Jersey, the day and year last aforesaid.

ROBERT S. PESCHLER

Notary Public – State of New Jersey

ROBERT S. PESCHLER

NOTARY PUBLIC OF NEW JERSEY

Comm. # 2427815

My Commission Expires 12/11/2022

EX-4.L

Exhibit 4(l)

FLORIDA POWER & LIGHT COMPANY

OFFICER’S CERTIFICATE

Creating the Floating Rate Notes, Series due January 12, 2024

Paul I. Cutler, Treasurer of Florida Power & Light Company (the “Company”), pursuant to the authority granted in the accompanying Board Resolutions (all capitalized terms used herein which are not defined herein or in Exhibit A hereto, but which are defined in the Indenture referred to below, shall have the meanings specified in the Indenture), and pursuant to Sections 201 and 301 of the Indenture, does hereby certify to The Bank of New York Mellon (the “Trustee”), as Trustee under the Indenture (For Unsecured Debt Securities) dated as of November 1, 2017 between the Company and the Trustee (the “Indenture”), that:

1.The securities to be issued under the Indenture in accordance with this certificate shall be designated “Floating Rate Notes, Series due January 12, 2024” (referred to herein as the “Notes of the Eleventh Series”) and shall be issued in substantially the form set forth as Exhibit A hereto.

2.The Notes of the Eleventh Series shall be issued by the Company in the initial aggregate principal amount of $1,000,000,000. Additional Notes of the Eleventh Series, without limitation as to amount, having the same terms as the Outstanding Notes of the Eleventh Series (except for the issue date of the additional Notes of the Eleventh Series and, if applicable, the initial Interest Payment Date (as defined in Exhibit A hereto)) may also be issued by the Company pursuant to the Indenture without the consent of the Holders of the then-Outstanding Notes of the Eleventh Series. Any such additional Notes of the Eleventh Series as may be issued pursuant to the Indenture from time to time shall be part of the same series as the then-Outstanding Notes of the Eleventh Series.

3.The Notes of the Eleventh Series shall mature and the principal shall be due and payable, together with all accrued and unpaid interest thereon, on the Stated Maturity Date. The “Stated Maturity Date” means January 12, 2024.

4.The Notes of the Eleventh Series shall bear interest as provided in the form set forth as Exhibit A hereto.

5.Each installment of interest on a Note of the Eleventh Series shall be payable as provided in the form set forth as Exhibit A hereto.

6.Registration of the Notes of the Eleventh Series, and registration of transfers and exchanges in respect of the Notes of the Eleventh Series, may be effectuated at the office or agency of the Company in New York City, New York. Notices and demands to or upon the Company in respect of the Notes of the Eleventh Series may be served at the office or agency of the Company in New York City, New York. The Corporate Trust Office of the Trustee will initially be the agency of the Company for such payment, registration, registration of transfers and exchanges and service of notices and demands, and the Company hereby appoints the Trustee as its agent for all such purposes; provided, however, that the Company reserves the right to change, by one or more Officer’s Certificates, any such office or agency and such agent. The Trustee will initially be the Security Registrar and the Paying Agent for the Notes of the Eleventh Series.

DB1/ 126667389.4

7.The Notes of the Eleventh Series will be redeemable at the option of the Company prior to the Stated Maturity Date as provided in the form set forth as Exhibit A hereto.

8.So long as all of the Notes of the Eleventh Series are held by a securities depository in book-entry form, the Regular Record Date for the interest payable on any given Interest Payment Date with respect to the Notes of the Eleventh Series shall be the close of business on the Business Day (as defined in Exhibit A hereto) immediately preceding such Interest Payment Date; provided, however, that if any of the Notes of the Eleventh Series are not held by a securities depository in book-entry form, the Regular Record Date will be the close of business on the fifteenth (15th) calendar day immediately preceding such Interest Payment Date.

9.If the Company shall make any deposit of money and/or Eligible Obligations with respect to any Notes of the Eleventh Series, or any portion of the principal amount thereof, as contemplated by Section 701 of the Indenture, the Company shall not deliver an Officer’s Certificate described in clause (z) in the first paragraph of said Section 701 unless the Company shall also deliver to the Trustee, together with such Officer’s Certificate, either:

(A)an instrument wherein the Company, notwithstanding the satisfaction and discharge of its indebtedness in respect of the Notes of the Eleventh Series, shall assume the obligation (which shall be absolute and unconditional) to irrevocably deposit with the Trustee or Paying Agent such additional sums of money, if any, or additional Eligible Obligations (meeting the requirements of said Section 701), if any, or any combination thereof, at such time or times, as shall be necessary, together with the money and/or Eligible Obligations theretofore so deposited, to pay when due the principal of and premium, if any, and interest due and to become due on such Notes of the Eleventh Series or portions thereof, all in accordance with and subject to the provisions of said Section 701; provided, however, that such instrument may state that the obligation of the Company to make additional deposits as aforesaid shall be subject to the delivery to the Company by the Trustee of a notice asserting the deficiency; or

(B)an Opinion of Counsel to the effect that, as a result of (i) the receipt by the Company from, or the publication by, the Internal Revenue Service of a ruling or (ii) a change in law occurring after the date of this certificate, the Holders of such Notes of the Eleventh Series, or the applicable portion of the principal amount thereof, will not recognize income, gain or loss for United States federal income tax purposes as a result of the satisfaction and discharge of the Company’s indebtedness in respect thereof and will be subject to United States federal income tax on the same amounts, at the same times and in the same manner as if such satisfaction and discharge had not been effectuated.

10.The Notes of the Eleventh Series will be initially issued in global form registered in the name of Cede & Co. (as nominee for The Depository Trust Company). The Notes of the Eleventh Series in global form shall bear the depository legend in substantially the form set forth as Exhibit A hereto. The Notes of the Eleventh Series in global form will contain restrictions on transfer, substantially as described in the form set forth as Exhibit A hereto.

11.No service charge shall be made for the registration of transfer or exchange of the Notes of the Eleventh Series; provided, however, that the Company may

2

DB1/ 126667389.4

require payment of a sum sufficient to cover any tax or other governmental charge that may be imposed in connection with such transfer or exchange.

12.The Eligible Obligations with respect to the Notes of the Eleventh Series shall be the Government Obligations and the Investment Securities.

13.The Notes of the Eleventh Series shall have such other terms and provisions as are provided in the form set forth as Exhibit A hereto.

14.The undersigned has read all of the covenants and conditions contained in the Indenture relating to the issuance of the Notes of the Eleventh Series and the definitions in the Indenture relating thereto and in respect of which this certificate is made.

15.The statements contained in this certificate are based upon the familiarity of the undersigned with the Indenture, the documents accompanying this certificate, and upon discussions by the undersigned with officers and employees of the Company familiar with the matters set forth herein.

16.In the opinion of the undersigned, he or she has made such examination or investigation as is necessary to enable him or her to express an informed opinion as to whether or not such covenants and conditions have been complied with.

17.In the opinion of the undersigned, such conditions and covenants and conditions precedent, if any (including any covenants compliance with which constitutes a condition precedent), to the authentication and delivery of the Notes of the Eleventh Series requested in the accompanying Company Order No. 12 have been complied with.

3

DB1/ 126667389.4

IN WITNESS WHEREOF, I have executed this Officer’s Certificate on behalf of the Company this 14th day of January, 2022 in Park City, Utah.

PAUL I. CUTLER            

Paul I. Cutler

Treasurer

Exhibit A

[Unless this certificate is presented by an authorized representative of The Depository Trust Company, a limited purpose company organized under the New York Banking Law (“DTC”), to Florida Power & Light Company or its agent for registration of transfer, exchange, or payment, and any certificate issued is registered in the name of Cede & Co. or in such other name as is requested by an authorized representative of DTC (and any payment is made to Cede & Co. or to such other entity as is requested by an authorized representative of DTC), ANY TRANSFER, PLEDGE, OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL inasmuch as the registered owner hereof, Cede & Co., has an interest herein.]

No. _______________                        CUSIP No. _________

[FORM OF FACE OF NOTE]

FLORIDA POWER & LIGHT COMPANY

FLOATING RATE NOTES, SERIES DUE JANUARY 12, 2024

FLORIDA POWER & LIGHT COMPANY, a corporation duly organized and existing under the laws of the State of Florida (herein referred to as the “Company,” which term includes any successor Person under the Indenture (as defined below)), for value received, hereby promises to pay to

, or registered assigns, the principal sum of ______________________ Dollars on January 12, 2024 (the “Stated Maturity Date”). The Company further promises to pay interest on the principal sum of this Floating Rate Note, Series due January 12, 2024 (this “Security”) to the registered Holder hereof at the Interest Rate (as defined on the reverse of this Security), in like coin or currency, quarterly on January 12, April 12, July 12, and October 12 of each year (each an “Interest Payment Date”) until the principal hereof is paid or duly provided for, such interest payments to commence on April 12, 2022. Interest on the Securities of this series will accrue (i) from and including January 14, 2022 to but excluding the first Interest Payment Date and thereafter will accrue from and including the last Interest Payment Date to which interest has either been paid or duly provided for to but excluding the next Interest Payment Date, (ii) in the case of the last such period, from and including the Interest Payment Date immediately preceding the Stated Maturity Date to but excluding the Stated Maturity Date, or (iii) in the case of a redemption of the Securities of this series, from and including the Interest Payment Date immediately preceding a Redemption Date (as defined on the reverse of this Security) to but excluding such Redemption Date (each an “Interest Period”). No interest will accrue on the Securities of this series with respect to the day on which the Securities of this series mature. The amount of interest payable for any Interest Period will be computed on the basis of a 360-day year and the actual number of days in the Observation Period (as defined on the reverse of this Security). The interest so payable, and punctually paid or duly provided for, on an Interest Payment Date will, as provided in the Indenture referred to on the reverse of this Security (the “Indenture”), be payable to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on the “Regular Record Date” for such interest installment which shall be the close of business on the Business Day immediately preceding such Interest Payment Date so long as all of the Securities of this series are held by a securities

A - 1

DB1/ 126667389.4

depository in book-entry form; provided that if any of the Securities of this series are not held by a securities depository in book-entry form, the Regular Record Date will be the close of business on the fifteenth (15th) calendar day immediately preceding such Interest Payment Date; and providedfurther that interest payable on the Stated Maturity Date or a Redemption Date will be paid to the same Person to whom the associated principal is to be paid. Any such interest not punctually paid or duly provided for will forthwith cease to be payable to the Person who is the Holder of this Security on such Regular Record Date and may be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date to be fixed by the Trustee for the payment of such Defaulted Interest, notice of which shall be given to Holders of Securities of this series not less than ten (10) days prior to such Special Record Date, or may be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Securities of this series may be listed, and upon such notice as may be required by such exchange, all as more fully provided in the Indenture.

Payment of the principal of (and premium, if any) and interest on this Security will be made at the office or agency of the Company maintained for that purpose in New York City, the State of New York in such coin or currency of the United States of America as at the time of payment is legal tender for payment of public and private debts; provided, however, that, at the option of the Company, interest on this Security may be paid by check mailed to the address of the Person entitled thereto, as such address shall appear on the Security Register or by a wire transfer to an account designated by the Person entitled thereto.

Reference is hereby made to the further provisions of this Security set forth on the reverse of this Security, which further provisions shall for all purposes have the same effect as if set forth at this place. (All capitalized terms used in this Security which are not defined herein, including the reverse of this Security, but which are defined in the Indenture or in the Officer’s Certificate, shall have the meanings specified in the Indenture or in the Officer’s Certificate.)

Unless the certificate of authentication hereon has been executed by the Trustee referred to on the reverse of this Security by manual signature, this Security shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

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DB1/ 126667389.4

IN WITNESS WHEREOF, the Company has caused this instrument to be duly executed in .

FLORIDA POWER & LIGHT COMPANY

By:_______________________________________

[FORM OF CERTIFICATE OF AUTHENTICATION]

CERTIFICATE OF AUTHENTICATION

Dated:

This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture.

THE BANK OF NEW YORK MELLON, as Trustee

By:_______________________________________

Authorized Signatory

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DB1/ 126667389.4

[FORM OF REVERSE OF NOTE]

This Security is one of a duly authorized issue of securities of the Company (herein called the “Securities”), issued and to be issued in one or more series under an Indenture (For Unsecured Debt Securities), dated as of November 1, 2017 (herein called the “Indenture,” which term shall have the meaning assigned to it in such instrument), between the Company and The Bank of New York Mellon, as Trustee (herein called the “Trustee,” which term includes any successor trustee under the Indenture), and reference is hereby made to the Indenture, including the Board Resolutions and Officer’s Certificate filed with the Trustee on January 14, 2022 creating the series designated on the face hereof (herein called the “Officer’s Certificate”), for a statement of the respective rights, limitations of rights, duties and immunities thereunder of the Company, the Trustee and the Holders of the Securities of this series and of the terms upon which the Securities of this series are, and are to be, authenticated and delivered. This Security is one of the series designated on the face hereof.

Interest and Payment.

The Securities of this series shall bear interest at a variable rate per annum (the “Interest Rate”) equal to Compounded SOFR (as defined below), plus 0.38% (0.38%, the “Margin”).

If any Interest Payment Date falls on a day that is not a Business Day, the Company will make the interest payment on the next succeeding Business Day unless that Business Day is in the next succeeding calendar month, in which case (other than in the case of the Stated Maturity Date or a Redemption Date) the Company will make the interest payment on the immediately preceding Business Day. If an interest payment is made on the next succeeding Business Day, no interest will accrue as a result of the delay in payment. If the Stated Maturity Date or a Redemption Date of the Securities of this series falls on a day that is not a Business Day, the payment due on such date will be postponed to the next succeeding Business Day, and no further interest will accrue in respect of such postponement.

On each Interest Payment Determination Date (as defined below) relating to the applicable Interest Payment Date, the Calculation Agent (as defined below) will calculate the amount of accrued interest payable on the Securities of this series by multiplying (i) the outstanding principal amount of the Securities of this series by (ii) the product of (a) the Interest Rate for the relevant Interest Period multiplied by (b) the quotient of the actual number of calendar days in such Observation Period divided by 360. In no event will the interest rate on the Securities of this series be less than zero.

“Calculation Agent” means a banking institution or trust company appointed by the Company to act as calculation agent, initially The Bank of New York Mellon.

Compounded SOFR. “Compounded SOFR” will be determined by the Calculation Agent in accordance with the following formula (and the resulting percentage will be rounded, if necessary, to the nearest one hundred-thousandth of a percentage point):

(	SOFR IndexEnd	-	)	x	360
	SOFR IndexStart				dc

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DB1/ 126667389.4

where:

“SOFR IndexStart” = For periods other than the initial Interest Period, the SOFR Index value on the preceding Interest Payment Determination Date, and, for the initial Interest Period, the SOFR Index value on January 12, 2022;

“SOFR IndexEnd” = The SOFR Index value on the Interest Payment Determination Date relating to the applicable Interest Payment Date (or, in the final Interest Period, relating to the Stated Maturity Date or, in the case of a redemption of the Securities of this series, relating to the applicable Redemption Date); and

“dc” is the number of calendar days in the relevant Observation Period.

For purposes of determining Compounded SOFR,

“Interest Payment Determination Date” means the date that is two U.S. Government Securities Business Days before each Interest Payment Date (or, in the final Interest Period, before the Stated Maturity Date or, in the case of a redemption of the Securities of this series, before the applicable Redemption Date).

“Observation Period” means, in respect of each Interest Period, the period from and including the date that is two U.S. Government Securities Business Days preceding the first date in such Interest Period to but excluding the date that is two U.S. Government Securities Business Days preceding the Interest Payment Date for such Interest Period (or, in the final Interest Period, preceding the Stated Maturity Date or, in the case of a redemption of the Securities of this series, preceding the applicable Redemption Date).

“SOFR Index” means, with respect to any U.S. Government Securities Business Day:

(1)the SOFR Index value as published by the SOFR Administrator (as defined below) as such index appears on the SOFR Administrator’s Website at 3:00 p.m. (New York time) on such U.S. Government Securities Business Day (the “SOFR Index Determination Time”); provided that:

(2)if a SOFR Index value does not so appear as specified in (1) above at the SOFR Index Determination Time, then: (i) if a Benchmark Transition Event and its related Benchmark Replacement Date (each, as defined below) have not occurred with respect to SOFR, then Compounded SOFR shall be the rate determined pursuant to the “SOFR Index Unavailable Provisions” described below; or (ii) if a Benchmark Transition Event and its related Benchmark Replacement Date have occurred with respect to SOFR, then Compounded SOFR shall be the rate determined pursuant to the “Effect of Benchmark Transition Event” provisions described below.

“SOFR” means the daily secured overnight financing rate as provided by the SOFR Administrator on the SOFR Administrator’s Website.

“SOFR Administrator” means the Federal Reserve Bank of New York (or a successor administrator of SOFR).

“SOFR Administrator’s Website” means the website of the Federal Reserve Bank of New York, currently at http://www.newyorkfed.org, or any successor source.

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“U.S. Government Securities Business Day” means any day except for a Saturday, a Sunday or a day on which the Securities Industry and Financial Markets Association recommends that the fixed income departments of its members be closed for the entire day for purposes of trading in U.S. government securities.

Notwithstanding anything to the contrary in the Securities of this series, the Officer’s Certificate or the Indenture, if the Company or its designee (which may be an independent financial advisor or any other designee of the Company (any of such entities, a “Designee”)) determines on or prior to the relevant Reference Time (as defined below) that a Benchmark Transition Event and its related Benchmark Replacement Date have occurred with respect to determining Compounded SOFR, then the benchmark replacement provisions set forth below under “Effect of Benchmark Transition Event” will thereafter apply to all determinations of the rate of interest payable on the Securities of this series.

For the avoidance of doubt, in accordance with the benchmark replacement provisions, after a Benchmark Transition Event and its related Benchmark Replacement Date have occurred, the Interest Rate for each Interest Period on the Securities of this series will be an annual rate equal to the sum of the Benchmark Replacement and the applicable margin.

SOFR Index Unavailable Provisions. If a SOFR IndexStart or SOFR IndexEnd is not published on the associated Interest Payment Determination Date and a Benchmark Transition Event and its related Benchmark Replacement Date have not occurred with respect to SOFR, “Compounded SOFR” means, for the applicable Interest Period for which such index is not available, the rate of return on a daily compounded interest investment calculated in accordance with the formula for SOFR Averages, and definitions required for such formula, published on the SOFR Administrator’s Website, initially located at https://www.newyorkfed.org/markets/treasury-repo-reference-rates-information. For the purposes of this provision, references in the SOFR Averages compounding formula and related definitions to “calculation period” shall be replaced with “Observation Period” and the words “that is, 30-, 90-, or 180-calendar days” shall be removed. If SOFR does not so appear for any day “i” in the Observation Period, SOFRi for such day “i” shall be SOFR published in respect of the first preceding U.S. Government Securities Business Day for which SOFR was published on the SOFR Administrator’s Website.

Absent willful misconduct, bad faith or manifest error, the calculation of the applicable Interest Rate for each Interest Period by the Calculation Agent or in certain circumstances described below, by the Company (or its Designee) will be final and binding on the Company, the Trustee, and the Holders of the Securities of this series.

None of the Trustee, Paying Agent, Security Registrar or Calculation Agent shall be under any obligation (i) to monitor, determine or verify the unavailability or cessation of SOFR or the SOFR Index, or whether or when there has occurred, or to give notice to any other transaction party of the occurrence of, any Benchmark Transition Event or related Benchmark Replacement Date, (ii) to select, determine or designate any Benchmark Replacement, or other successor or replacement benchmark index, or whether any conditions to the designation of such a rate or index have been satisfied, (iii) to select, determine or designate any Benchmark Replacement Adjustment (as defined below), or other modifier to any replacement or successor index, or (iv) to determine whether or what Benchmark Replacement Conforming Changes (as defined below) are necessary or advisable, if any, in connection with any of the foregoing. In connection with the foregoing, each of the Trustee, Paying Agent and Registrar and Calculation Agent shall be entitled to conclusively rely on any determinations made by the Company (or its

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Designee) without independent investigation, and none will have any liability for actions taken at the direction of the Company in connection therewith.

None of the Trustee, Paying Agent, Security Registrar or Calculation Agent shall be liable for any inability, failure or delay on its part to perform any of its duties described in the Securities of this series, the Officer’s Certificate or the Indenture as a result of the unavailability of SOFR, the SOFR Index or other applicable Benchmark Replacement, including as a result of any failure, inability, delay, error or inaccuracy on the part of any other transaction party in providing any direction, instruction, notice or information contemplated by the Securities of this series, the Officer’s Certificate or the Indenture and reasonably required for the performance of such duties. In connection with any determinations made under the subsection “Effect of Benchmark Transition Event” below, none of the Trustee, Paying Agent, Registrar or Calculation Agent shall be responsible or liable for the actions or omissions of the Company (or its Designee), or for any failure or delay in the performance by the Company (or its Designee), nor shall any of the Trustee, Paying Agent, Registrar or Calculation Agent be under any obligation to oversee or monitor the performance of the Company (or its Designee).

Effect of Benchmark Transition Event.

Benchmark Replacement. If the Company (or its Designee) determines that a Benchmark Transition Event and its related Benchmark Replacement Date have occurred prior to the Reference Time in respect of any determination of the Benchmark on any date, the Benchmark Replacement will replace the then-current Benchmark for all purposes relating to the Securities of this series in respect of such determination on such date and all determinations on all subsequent dates.

Benchmark Replacement Conforming Changes. In connection with the implementation of a Benchmark Replacement, the Company (or its Designee) will have the right to make Benchmark Replacement Conforming Changes from time to time.

Decisions and Determinations. Any determination, decision or election that may be made by the Company (or its Designee) pursuant to the benchmark replacement provisions described in this subsection “Effect of Benchmark Transition Event,” including any determination with respect to tenor, rate or adjustment or of the occurrence or non-occurrence of an event, circumstance or date and any decision to take or refrain from taking any action or any selection, will be conclusive and binding absent manifest error, will be made in the Company’s (or its Designee’s) sole discretion, and, notwithstanding anything to the contrary in the Securities of this series, the Officer’s Certificate or the Indenture, shall become effective without consent from the holders of the Securities of this series or any other party.

Certain Defined Terms. As used herein, the following terms have the following meanings:

“Benchmark” means, initially, Compounded SOFR; provided that if a Benchmark Transition Event and its related Benchmark Replacement Date have occurred with respect to Compounded SOFR (or the published SOFR Index used in the calculation thereof) or the then-current Benchmark, then “Benchmark” means the applicable Benchmark Replacement.

“Benchmark Replacement” means the Interpolated Benchmark with respect to the then-current Benchmark, plus the Benchmark Replacement Adjustment for such Benchmark; provided

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that if the Company (or its Designee) cannot determine the Interpolated Benchmark as of the Benchmark Replacement Date, then “Benchmark Replacement” means the first alternative set forth in the order below that can be determined by the Company (or its Designee) as of the Benchmark Replacement Date:

(1)the sum of: (a) the alternate rate of interest that has been selected or recommended by the Relevant Governmental Body as the replacement for the then-current Benchmark for the applicable Corresponding Tenor and (b) the Benchmark Replacement Adjustment;

(2)the sum of: (a) the ISDA Fallback Rate and (b) the Benchmark Replacement Adjustment; and

(3)the sum of: (a) the alternate rate of interest that has been selected by the Company (or its Designee) as the replacement for the then-current Benchmark for the applicable Corresponding Tenor giving due consideration to any industry-accepted rate of interest as a replacement for the then-current Benchmark for U.S. dollar denominated floating rate notes at such time and (b) the Benchmark Replacement Adjustment.

“Benchmark Replacement Adjustment” means the first alternative set forth in the order below that can be determined by the Company (or its Designee) as of the Benchmark Replacement Date:

(1)the spread adjustment, or method for calculating or determining such spread adjustment (which may be a positive or negative value or zero), that has been selected or recommended by the Relevant Governmental Body for the applicable Unadjusted Benchmark Replacement;

(2)if the applicable Unadjusted Benchmark Replacement is equivalent to the ISDA Fallback Rate, then the ISDA Fallback Adjustment; and

(3)the spread adjustment (which may be a positive or negative value or zero) that has been selected by the Company (or its Designee) giving due consideration to any industry-accepted spread adjustment, or method for calculating or determining such spread adjustment, for the replacement of the then-current Benchmark with the applicable Unadjusted Benchmark Replacement for U.S. dollar denominated floating rate notes at such time.

The Benchmark Replacement Adjustment shall not include the Margin specified herein and such Margin shall be applied to the Benchmark Replacement to determine the interest payable on the Securities of this series.

“Benchmark Replacement Conforming Changes” means, with respect to any Benchmark Replacement, any technical, administrative or operational changes (including changes to the definitions or interpretations of “Interest Period”, the timing and frequency of determining rates and making payments of interest, the rounding of amounts or tenors, and other administrative matters) that the Company (or its Designee) decides may be appropriate to reflect the adoption of such Benchmark Replacement in a manner substantially consistent with market practice (or, if the Company (or its Designee) decides that adoption of any portion of such market practice is not administratively feasible or if the Company (or its Designee) determines

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that no market practice for use of the Benchmark Replacement exists, in such other manner as the Company (or its Designee) determines is reasonably necessary or practicable).

“Benchmark Replacement Date” means the earliest to occur of the following events with respect to the then-current Benchmark:

(1)in the case of clause (1) or (2) of the definition of “Benchmark Transition Event,” the later of (a) the date of the public statement or publication of information referenced therein and (b) the date on which the administrator of the Benchmark permanently or indefinitely ceases to provide the Benchmark; or

(2)in the case of clause (3) of the definition of “Benchmark Transition Event,” the date of the public statement or publication of information referenced therein.

For the avoidance of doubt, if the event giving rise to the Benchmark Replacement Date occurs on the same day as, but earlier than, the Reference Time in respect of any determination, the Benchmark Replacement Date will be deemed to have occurred prior to the Reference Time for such determination.

“Benchmark Transition Event” means the occurrence of one or more of the following events with respect to the then-current Benchmark:

(1)a public statement or publication of information by or on behalf of the administrator of the Benchmark announcing that such administrator has ceased or will cease to provide the Benchmark, permanently or indefinitely, provided that, at the time of such statement or publication, there is no successor administrator that will continue to provide the Benchmark;

(2)a public statement or publication of information by the regulatory supervisor for the administrator of the Benchmark, the central bank for the currency of the Benchmark, an insolvency official with jurisdiction over the administrator for the Benchmark, a resolution authority with jurisdiction over the administrator for the Benchmark or a court or an entity with similar insolvency or resolution authority over the administrator for the Benchmark, which states that the administrator of the Benchmark has ceased or will cease to provide the Benchmark permanently or indefinitely, provided that, at the time of such statement or publication, there is no successor administrator that will continue to provide the Benchmark; or

(3)a public statement or publication of information by the regulatory supervisor for the administrator of the Benchmark announcing that the Benchmark is no longer representative.

“Business Day” is any day that is not a Saturday, a Sunday, or a day on which banking institutions or trust companies in New York City are generally authorized or required by law or executive order to remain closed.

“Corresponding Tenor” with respect to a Benchmark Replacement means a tenor (including overnight) having approximately the same length (disregarding business day adjustment) as the applicable tenor for the then-current Benchmark.

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“Interpolated Benchmark” with respect to the Benchmark means the rate determined for the Corresponding Tenor by interpolating on a linear basis between: (1) the Benchmark for the longest period (for which the Benchmark is available) that is shorter than the Corresponding Tenor and (2) the Benchmark for the shortest period (for which the Benchmark is available) that is longer than the Corresponding Tenor.

“ISDA Definitions” means the 2006 ISDA Definitions published by the International Swaps and Derivatives Association, Inc. or any successor thereto, as amended or supplemented from time to time, or any successor definitional booklet for interest rate derivatives published from time to time.

“ISDA Fallback Adjustment” means the spread adjustment (which may be a positive or negative value or zero) that would apply for derivatives transactions referencing the ISDA Definitions to be determined upon the occurrence of an index cessation event with respect to the Benchmark for the applicable tenor.

“ISDA Fallback Rate” means the rate that would apply for derivatives transactions referencing the ISDA Definitions to be effective upon the occurrence of an index cessation date with respect to the Benchmark for the applicable tenor excluding the applicable ISDA Fallback Adjustment.

“Reference Time” with respect to any determination of the Benchmark means (1) if the Benchmark is Compounded SOFR, the SOFR Index Determination Time, as such time is defined above, and (2) if the Benchmark is not Compounded SOFR, the time determined by the Company (or its Designee) in accordance with the Benchmark Replacement Conforming Changes.

“Relevant Governmental Body” means the Federal Reserve Board and/or the Federal Reserve Bank of New York, or a committee officially endorsed or convened by the Federal Reserve Board and/or the Federal Reserve Bank of New York or any successor thereto.

“Unadjusted Benchmark Replacement” means the Benchmark Replacement excluding the Benchmark Replacement Adjustment.

Redemption.

The Securities of this series shall be redeemable at the option of the Company in whole at any time, or in part from time to time, on or after July 12, 2022 (each a “Redemption Date”), upon notice (the “Redemption Notice”) mailed at least ten (10) days but not more than sixty (60) days prior to a Redemption Date at a price (the “Redemption Price”) equal to 100% of the principal amount of the Securities of this series being redeemed plus accrued and unpaid interest, if any, on the Securities of this series being redeemed to but excluding the Redemption Date.

If at the time the Redemption Notice is given, the redemption moneys are not on deposit with the Trustee, then, if such notice so provides, the redemption shall be subject to the receipt of the redemption moneys on or before the Redemption Date and such Redemption Notice shall be of no force or effect unless such moneys are received.

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Upon payment of the Redemption Price, on and after the Redemption Date interest will cease to accrue on the Securities of this series or portions thereof called for redemption.

The Indenture contains provisions for defeasance at any time of the entire indebtedness of this Security upon compliance with certain conditions set forth in the Indenture, including the Officer’s Certificate described above.

If an Event of Default with respect to Securities of this series shall occur and be continuing, the principal of and interest on the Securities of this series may be declared due and payable in the manner and with the effect provided in the Indenture.

The Indenture permits, with certain exceptions as therein provided, the amendment thereof and the modification of the rights and obligations of the Company and the rights of the Holders of the Securities of each series to be affected by such amendment to the Indenture at any time by the Company and the Trustee with the consent of the Holders of a majority in principal amount of the Securities at the time Outstanding of all series to be thus affected. The Indenture also contains provisions permitting the Holders of specified percentages in principal amount of the Securities of each series at the time Outstanding, on behalf of the Holders of all Securities of such series, to waive compliance by the Company with certain provisions of the Indenture and certain past defaults under the Indenture and their consequences. Any such consent or waiver by Holders of the specified percentages in principal amount of the Securities of this series shall be conclusive and binding upon all current and future Holders of this Security and of any Security issued upon the registration of transfer hereof or in exchange herefor or in lieu hereof, whether or not notation of such consent or waiver is made upon this Security.

As provided in and subject to the provisions of the Indenture, the Holder of this Security shall not have the right to institute any proceeding with respect to the Indenture or for the appointment of a receiver or trustee or for any other remedy thereunder, unless such Holder shall have previously given the Trustee written notice of a continuing Event of Default with respect to the Securities of this series, the Holders of a majority in aggregate principal amount of the Securities of all series at the time Outstanding in respect of which an Event of Default shall have occurred and be continuing shall have made written request to the Trustee to institute proceedings in respect of such Event of Default as Trustee and offered the Trustee reasonable indemnity, and the Trustee shall not have received from the Holders of a majority in aggregate principal amount of Securities of all series at the time Outstanding in respect of which an Event of Default shall have occurred and be continuing a direction inconsistent with such request, and shall have failed to institute any such proceeding, for sixty (60) days after receipt of such notice, request and offer of indemnity. The foregoing shall not apply to any suit instituted by the Holder of this Security for the enforcement of any payment of principal hereof or any premium or interest hereon on or after the respective due dates expressed herein.

No reference herein to the Indenture and no provision of this Security or of the Indenture shall alter or impair the obligation of the Company, which is absolute and unconditional, to pay the principal of and any premium and interest on this Security at the times, place and rate, and in the coin or currency, herein prescribed.

The Securities of this series are issuable only in registered form without coupons in minimum denominations of $2,000 and integral multiples of $1,000 in excess thereof. As provided in the Indenture and subject to certain limitations therein set forth, Securities of this

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series are exchangeable for a like aggregate principal amount of Securities of this series and of like tenor and of authorized denominations, as requested by the Holder surrendering the same.

No service charge shall be made for any such registration of transfer or exchange, but the Company may require payment of a sum sufficient to cover any tax or other governmental charge that may be imposed in connection therewith.

The Company, the Trustee and any agent of the Company or the Trustee may treat the Person in whose name this Security is registered as the absolute owner hereof for all purposes, whether or not this Security be overdue, and none of the Company, the Trustee or any such agent shall be affected by notice to the contrary.

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EX-10.JJ

Exhibit 10(jj)

NEXTERA ENERGY, INC.

NON-EMPLOYEE DIRECTOR COMPENSATION SUMMARY

(Effective January 1, 2022)

Annual Retainer      (payable quarterly in common stock or cash)	$110,000
Board or Committee meeting fee	$2,000/meeting
Audit Committee Chair retainer (annual)      (payable quarterly)	$25,000
Lead Director retainer (annual)      (payable quarterly)	$30,000
Compensation and Nuclear Committee Chair retainer (annual)      (payable quarterly)	$25,000
Other Committee Chair retainer (annual)      (payable quarterly)	$20,000
Annual grant of restricted stock      (under 2017 Non-Employee Directors Stock Plan)	That number of shares determined by dividing $185,000 by closing price of NextEra Energy common stock on effective date of grant (rounded up to the nearest 10 shares)
Miscellaneous	- Travel and Accident Insurance (including spouse coverage)
	- Travel and related expenses while on Board business, and actual administrative or similar expenses incurred for Board or Committee business, are paid or reimbursed by the Company. Directors may travel on Company aircraft in accordance with the Company’s Aviation Policy (primarily to or from Board meetings and while on Board business; in limited circumstances for other reasons if the Company would incur little if any incremental cost, space is available and the aircraft is already in use for another authorized purpose - may be accompanied by immediate family members when space is available).
	- Directors may participate in the Company’s Deferred Compensation Plan.
	- Directors may participate in the Company’s matching gift program, which matches gifts to educational institutions to a maximum of $10,000 per donor.

EX-21

Exhibit 21

SUBSIDIARIES OF NEXTERA ENERGY, INC.

NextEra Energy, Inc.'s principal subsidiaries as of December 31, 2021 are listed below.

	Subsidiary	State or Jurisdiction of Incorporation or Organization
1.	Florida Power & Light Company (100%-owned)	Florida
2.	NextEra Energy Capital Holdings, Inc. (100%-owned)	Florida
3.	NextEra Energy Resources, LLC(a)(b)	Delaware
4.	Palms Insurance Company, Limited(b)	Cayman Islands
5.	Palms SC Insurance Company, LLC(b)	South Carolina

__________________

(a)    Includes 1,495 subsidiaries that operate in the United States and 152 subsidiaries that operate in foreign countries in the same line of business as NextEra Energy Resources, LLC.

(b)    100%-owned subsidiary of NextEra Energy Capital Holdings, Inc.

EX-22

Exhibit 22

GUARANTEED SECURITIES

Pursuant to Item 601(b)(22) of Regulation S-K, set forth below are securities issued by NextEra Energy Capital Holdings, Inc. (Issuer) and guaranteed by NextEra Energy, Inc. (Guarantor).

Issued under the Indenture (For Unsecured Debt Securities), dated as of June 1, 1999

3.55% Debentures, Series due May 1, 2027

Floating Rate Debentures, Series due February 25, 2022

3.50% Debentures, Series due April 1, 2029

Series J Debentures due September 1, 2024

2.75% Debentures, Series due November 1, 2029

Series K Debentures due March 1, 2025

2.25% Debentures, Series due June 1, 2030

Series L Debentures, Series due September 1, 2025

Floating Rate Debentures, Series due February 22, 2023

0.65% Debentures, Series due March 1, 2023

Floating Rate Debentures, Series due March 1, 2023

1.90% Debentures, Series due June 15, 2028

Floating Rate Debentures, Series due November 3, 2023

1.875% Debentures, Series due January 15, 2027

2.44% Debentures, Series due January 15, 2032

3.00% Debentures, Series due January 15, 2052

Issued under the Indenture (For Unsecured Subordinated Debt Securities), dated as of June 1, 2006

Series B Enhanced Junior Subordinated Debentures due 2066

Series C Junior Subordinated Debentures due 2067

Series L Junior Subordinated Debentures due September 29, 2057

Series M Junior Subordinated Debentures due December 1, 2077

Series N Junior Subordinated Debentures due March 1, 2079

Series O Junior Subordinated Debentures due May 1, 2079

Series P Junior Subordinated Debentures due March 15, 2082

EX-23

Exhibit 23

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in the following Registration Statements of our reports dated February 17, 2022, relating to the consolidated financial statements of NextEra Energy, Inc. and subsidiaries (NEE) and Florida Power & Light Company and subsidiaries (FPL) and the effectiveness of NEE's and FPL's internal control over financial reporting appearing in this Annual Report on Form 10-K of NEE and FPL for the year ended December 31, 2021:

NEE		FPL
Form S-8	No. 33-57673	Form S-3	No. 333-254632-01
Form S-8	No. 333-27079
Form S-8	No. 333-88067
Form S-8	No. 333-114911
Form S-8	No. 333-116501
Form S-8	No. 333-130479
Form S-8	No. 333-143739
Form S-8	No. 333-174799
Form S-8	No. 333-220136
Form S-8	No. 333-257141
Form S-3	No. 333-203453
Form S-3	No. 333-254632

DELOITTE & TOUCHE LLP

Boca Raton, Florida

February 17, 2022

EX-31.A

Exhibit 31(a)

Rule 13a-14(a)/15d-14(a) Certification

I, James L. Robo, certify that:

1.I have reviewed this Form 10-K for the annual period ended December 31, 2021 of NextEra Energy, Inc. (the registrant);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: February 17, 2022

JAMES L. ROBO

James L. Robo
Chairman, President and Chief Executive Officer
of NextEra Energy, Inc.

EX-31.B

Exhibit 31(b)

Rule 13a-14(a)/15d-14(a) Certification

I, Rebecca J. Kujawa, certify that:

1.I have reviewed this Form 10-K for the annual period ended December 31, 2021 of NextEra Energy, Inc. (the registrant);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: February 17, 2022

REBECCA J. KUJAWA

Rebecca J. Kujawa
Executive Vice President, Finance and
Chief Financial Officer
of NextEra Energy, Inc.

EX-31.C

Exhibit 31(c)

Rule 13a-14(a)/15d-14(a) Certification

I, Eric E. Silagy, certify that:

1.I have reviewed this Form 10-K for the annual period ended December 31, 2021 of Florida Power & Light Company (the registrant);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: February 17, 2022

ERIC E. SILAGY

Eric E. Silagy
President and Chief Executive Officer
of Florida Power & Light Company

EX-31.D

Exhibit 31(d)

Rule 13a-14(a)/15d-14(a) Certification

I, Rebecca J. Kujawa, certify that:

1.I have reviewed this Form 10-K for the annual period ended December 31, 2021 of Florida Power & Light Company (the registrant);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: February 17, 2022

REBECCA J. KUJAWA

Rebecca J. Kujawa
Executive Vice President, Finance
and Chief Financial Officer
of Florida Power & Light Company

EX-32.A

Exhibit 32(a)

Section 1350 Certification

We, James L. Robo and Rebecca J. Kujawa, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Annual Report on Form 10-K of NextEra Energy, Inc. (the registrant) for the annual period ended December 31, 2021 (Report) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

Dated: February 17, 2022

JAMES L. ROBO

James L. Robo
Chairman, President and Chief Executive Officer
of NextEra Energy, Inc.

REBECCA J. KUJAWA

Rebecca J. Kujawa
Executive Vice President, Finance and
Chief Financial Officer
of NextEra Energy, Inc.

A signed original of this written statement required by Section 906 has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

The foregoing certification is being furnished as an exhibit to the Report pursuant to Item 601(b)(32) of Regulation S-K and Section 906 of the Sarbanes-Oxley Act of 2002 and, accordingly, is not being filed with the Securities and Exchange Commission as part of the Report and is not to be incorporated by reference into any filing of the registrant under the Securities Act of 1933 or the Securities Exchange Act of 1934 (whether made before or after the date of the Report, irrespective of any general incorporation language contained in such filing).

EX-32.B

Exhibit 32(b)

Section 1350 Certification

We, Eric E. Silagy and Rebecca J. Kujawa, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Annual Report on Form 10-K of Florida Power & Light Company (the registrant) for the annual period ended December 31, 2021 (Report) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

Dated: February 17, 2022

ERIC E. SILAGY

Eric E. Silagy
President and Chief Executive Officer
of Florida Power & Light Company

REBECCA J. KUJAWA

Rebecca J. Kujawa
Executive Vice President, Finance
and Chief Financial Officer
of Florida Power & Light Company

A signed original of this written statement required by Section 906 has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

The foregoing certification is being furnished as an exhibit to the Report pursuant to Item 601(b)(32) of Regulation S-K and Section 906 of the Sarbanes-Oxley Act of 2002 and, accordingly, is not being filed with the Securities and Exchange Commission as part of the Report and is not to be incorporated by reference into any filing of the registrant under the Securities Act of 1933 or the Securities Exchange Act of 1934 (whether made before or after the date of the Report, irrespective of any general incorporation language contained in such filing).

XML

Document and Entity Information - USD ($)

12 Months Ended

Dec. 31, 2021

Jan. 31, 2022

Jun. 30, 2021

Entity Information [Line Items]

Document Type

10-K

Document Annual Report

true

Document Period End Date

Dec. 31, 2021

Document Transition Report

false

Entity File Number

1-8841

Entity Registrant Name

NEXTERA ENERGY INC

Entity Tax Identification Number

59-2449419

Entity Address, Address Line One

700 Universe Boulevard

Entity Address, City or Town

Juno Beach

Entity Address, State or Province

FL

Entity Address, Postal Zip Code

33408

City Area Code

561

Local Phone Number

694-4000

Entity Incorporation, State or Country Code

FL

Entity Well-known Seasoned Issuer

Yes

Entity Voluntary Filers

No

Entity Current Reporting Status

Yes

Entity Interactive Data Current

Yes

Entity Filer Category

Large Accelerated Filer

Entity Small Business

false

Entity Emerging Growth Company

false

Entity Shell Company

false

Entity Public Float

$ 143,450,834,024

Entity Common Stock, Shares Outstanding

1,962,744,998

Entity Central Index Key

0000753308

Current Fiscal Year End Date

--12-31

Document Fiscal Year Focus

2021

Document Fiscal Period Focus

FY

Amendment Flag

false

ICFR Auditor Attestation Flag

true

Documents Incorporated by Reference

Portions of NextEra Energy, Inc.'s Proxy Statement for the 2022 Annual Meeting of Shareholders are incorporated by reference in Part III hereof.

__________________________________

This combined Form 10-K represents separate filings by NextEra Energy, Inc. and Florida Power & Light Company. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Florida Power & Light Company makes no representations as to the information relating to NextEra Energy, Inc.'s other operations.

Florida Power & Light Company meets the conditions set forth in General Instruction I.(1)(a) and (b) of Form 10-K and is therefore filing this Form with the reduced disclosure format.

Common Stock [Member]

Entity Information [Line Items]

Title of 12(b) Security

Common Stock, $0.01 Par Value

Trading Symbol

NEE

Security Exchange Name

NYSE

Corporate Units [Member]

Entity Information [Line Items]

Title of 12(b) Security

4.872% Corporate Units

Trading Symbol

NEE.PRO

Security Exchange Name

NYSE

Corporate Units 5.279% [Member]

Entity Information [Line Items]

Title of 12(b) Security

5.279% Corporate Units

Trading Symbol

NEE.PRP

Security Exchange Name

NYSE

Corporate Units 6.219% [Member]

Entity Information [Line Items]

Title of 12(b) Security

6.219% Corporate Units

Trading Symbol

NEE.PRQ

Security Exchange Name

NYSE

FPL [Member]

Entity Information [Line Items]

Entity File Number

2-27612

Entity Registrant Name

FLORIDA POWER & LIGHT CO

Entity Tax Identification Number

59-0247775

Entity Well-known Seasoned Issuer

Yes

Entity Voluntary Filers

No

Entity Current Reporting Status

Yes

Entity Interactive Data Current

Yes

Entity Filer Category

Non-accelerated Filer

Entity Small Business

false

Entity Emerging Growth Company

false

Entity Shell Company

false

Entity Common Stock, Shares Outstanding

1,000

Entity Central Index Key

0000037634

Current Fiscal Year End Date

--12-31

XML

Audit Information	12 Months Ended
	Dec. 31, 2021
Auditor Information [Abstract]
Auditor Name	Deloitte & Touche LLP
Auditor Location	Boca Raton, Florida
Auditor Firm ID	34

XML

CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020		Dec. 31, 2019
OPERATING REVENUES		$ 17,069	$ 17,997		$ 19,204
OPERATING EXPENSES
Fuel, purchased power and interchange		4,527	3,539		4,363
Other operations and maintenance		3,953	3,751		3,640
Storm restoration costs		28	183		234
Depreciation and amortization		3,924	4,052		4,216
Taxes other than income taxes and other – net		1,801	1,709		1,804
Total operating expenses – net		14,233	13,234		14,257
GAINS ON DISPOSAL OF BUSINESSES/ASSETS – NET		77	353		406
Operating income		2,913	5,116		5,353
OTHER INCOME (DEDUCTIONS)
Interest Expense		(1,270)	(1,950)		(2,249)
Equity in earnings (losses) of equity method investees		666	(1,351)		66
Allowance for equity funds used during construction		142	93		67
Gains on disposal of investments and other property – net		70	50		55
Change in unrealized gains (losses) on equity securities held in NEER's nuclear decommissioning funds – net		267	163		238
Other net periodic benefit income		257	200		185
Other – net		130	92		121
Total other income (deductions) – net		262	(2,703)		(1,517)
INCOME BEFORE INCOME TAXES		3,175	2,413		3,836
INCOME TAXES		348	44		448
NET INCOME		2,827	2,369		3,388
NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS		746	550		381
NET INCOME ATTRIBUTABLE TO NEE		$ 3,573	$ 2,919		$ 3,769
Earnings per share attributable to NEE:
Basic		$ 1.82	$ 1.49		$ 1.95
Assuming dilution		$ 1.81	$ 1.48		$ 1.94
FPL [Member]
OPERATING REVENUES		$ 14,102	$ 13,060	[1]	$ 13,680	[1]
OPERATING EXPENSES
Fuel, purchased power and interchange		3,956	3,060	[1]	3,802	[1]
Other operations and maintenance		1,803	1,707	[1]	1,790	[1]
Storm restoration costs		28	183	[1]	234	[1]
Depreciation and amortization		2,266	2,526	[1]	2,771	[1]
Taxes other than income taxes and other – net		1,533	1,464	[1]	1,504	[1]
Total operating expenses – net		9,586	8,940	[1]	10,101	[1]
Operating income		4,516	4,120	[1]	3,579	[1]
OTHER INCOME (DEDUCTIONS)
Interest Expense		(615)	(641)	[1]	(649)	[1]
Allowance for equity funds used during construction		132	87	[1]	66	[1]
Other – net		11	2	[1]	7	[1]
Total other income (deductions) – net		(472)	(552)	[1]	(576)	[1]
INCOME BEFORE INCOME TAXES		4,044	3,568	[1]	3,003	[1]
INCOME TAXES		838	678	[1]	484	[1]
NET INCOME	[2]	$ 3,206	$ 2,890	[1]	$ 2,519	[1]

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

[2] FPL's comprehensive income is the same as reported net income.

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 2,827	$ 2,369	$ 3,388
Reclassification of unrealized losses on cash flow hedges from accumulated other comprehensive income (loss) to net income	6	12	29
Net unrealized gains (losses) on securities still held	(11)	12	20
Reclassification from accumulated other comprehensive income (loss) to net income	(4)	(3)	(2)
Defined benefit pension and other benefits plans:
Net unrealized gain (loss) and unrecognized prior service benefit (cost)	95	37	(46)
Reclassification from accumulated other comprehensive income (loss) to net income	5	2	(3)
Net unrealized gains (losses) on foreign currency translation	(1)	13	22
Other comprehensive income related to equity method investee	1	1	1
Total other comprehensive income, net of tax	91	74	21
Impact of Disposal of a Business	0	10	0
COMPREHENSIVE INCOME	2,918	2,453	3,409
COMPREHENSIVE LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	747	543	380
COMPREHENSIVE INCOME ATTRIBUTABLE TO NEE	$ 3,665	$ 2,996	$ 3,789

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement of Comprehensive Income [Abstract]
Reclassification of unrealized losses on cash flow hedges from accumulated other comprehensive income (loss) to net income, tax expense (benefit)	$ (2)	$ (4)	$ 8
Net unrealized gains (losses) on securities still held, tax expense (benefit)	(4)	4	8
Reclassification from accumulated other comprehensive income (loss) to net income, tax expense (benefit)	2	1	(1)
Net gain (loss) and prior service benefit (cost), tax expense (benefit)	30	11	(14)
Reclassification from accumulated other comprehensive income (loss) to net income, tax expense (benefit)	(1)	(1)	(1)
Other comprehensive income (loss) related to equity method investee, tax expense (benefit)	$ 1	1	$ 0
Impact on Disposal, Tax		$ (19)

XML

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 639	$ 1,105
Customer receivables, net	3,378	2,263
Other receivables	730	711
Materials, supplies and fuel inventory	1,561	1,552
Regulatory assets	1,125	377
Derivatives	689	570
Other	1,166	804
Total current assets	9,288	7,382
Other assets:
Property, plant and equipment – net	99,348	91,803
Special use funds	8,922	7,779
Investment in equity method investees	6,159	5,728
Prepaid benefit costs	2,243	1,707
Regulatory assets	4,578	3,712
Derivatives	1,135	1,647
Goodwill	4,844	4,254
Other	4,395	3,672
Total other assets	131,624	120,302
TOTAL ASSETS	140,912	127,684
Current liabilities:
Commercial paper	1,382	1,551
Other short-term debt	700	458
Current portion of long-term debt	1,785	4,138
Accounts payable	6,935	4,615
Customer deposits	485	474
Accrued interest and taxes	525	519
Derivatives	1,263	311
Accrued construction-related expenditures	1,378	991
Regulatory liabilities	289	245
Other	2,695	2,256
Total current liabilities	17,437	15,558
Other liabilities and deferred credits:
Long-term debt	50,960	41,944
Asset retirement obligations	3,082	3,057
Deferred income taxes	8,310	8,020
Regulatory liabilities	11,273	10,735
Derivatives	1,713	1,199
Other	2,468	2,242
Total other liabilities and deferred credits	77,806	67,197
TOTAL LIABILITIES	95,243	82,755
COMMITMENTS AND CONTINGENCIES
REDEEMABLE NONCONTROLLING INTERESTS – VIE	245	0
EQUITY
Common stock	20	20
Additional paid-in capital	11,271	11,222
Retained earnings	25,911	25,363
Accumulated Other Comprehensive Income (Loss), Net of Tax	0	(92)
Total common shareholders' equity	37,202	36,513
Noncontrolling interests	8,222	8,416
TOTAL EQUITY	45,424	44,929
TOTAL LIABILITIES, REDEEMABLE NONCONTROLLING INTERESTS AND EQUITY	140,912	127,684
FPL [Member]
Current assets:
Cash and cash equivalents	55	25	[1]
Customer receivables, net	1,297	1,141	[1]
Other receivables	350	405	[1]
Materials, supplies and fuel inventory	963	899	[1]
Regulatory assets	1,111	360	[1]
Other	142	182	[1]
Total current assets	3,918	3,012	[1]
Other assets:
Electric utility plant and other property – net	58,227	53,879	[1]
Special use funds	6,158	5,347	[1]
Prepaid benefit costs	1,657	1,550	[1]
Regulatory assets	4,343	3,399	[1]
Goodwill	2,989	2,989	[1]
Other	775	825	[1]
Total other assets	74,149	67,989	[1]
TOTAL ASSETS	78,067	71,001	[1]
Current liabilities:
Commercial paper	1,382	1,551	[1]
Other short-term debt	200	200	[1]
Current portion of long-term debt	536	354	[1]
Accounts payable	1,318	874	[1]
Customer deposits	478	468	[1]
Accrued interest and taxes	322	300	[1]
Accrued construction-related expenditures	601	423	[1]
Regulatory liabilities	278	224	[1]
Other	643	948	[1]
Total current liabilities	5,758	5,342	[1]
Other liabilities and deferred credits:
Long-term debt	17,974	16,882	[1]
Asset retirement obligations	2,049	1,871	[1]
Deferred income taxes	7,137	6,519	[1]
Regulatory liabilities	11,053	10,600
Other	502	559	[1]
Total other liabilities and deferred credits	38,715	36,431	[1]
TOTAL LIABILITIES	44,473	41,773	[1]
COMMITMENTS AND CONTINGENCIES			[1]
EQUITY
Common stock	1,373	1,373	[1]
Additional paid-in capital	19,936	18,236	[1]
Retained earnings	12,285	9,619	[1]
Total common shareholders' equity	33,594	29,228	[2]
TOTAL EQUITY	33,594	29,228	[1]
TOTAL LIABILITIES, REDEEMABLE NONCONTROLLING INTERESTS AND EQUITY	$ 78,067	$ 71,001	[1]

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

[2] 2020 and 2019 amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

XML

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Customer receivables, net of allowances	$ 35	$ 67
Property, plant and equipment – net	99,348	91,803
Current portion of long-term debt	1,785	4,138
Accounts payable	6,935	4,615
Long-term debt	$ 50,960	$ 41,944
Common stock, par value (usd per share)	$ 0.01	$ 0.01
Common stock, authorized (in shares)	3,200,000,000	3,200,000,000
Common stock, outstanding (in shares)	1,963,000,000	1,960,000,000
Variable Interest Entity, Primary Beneficiary [Member]
Property, plant and equipment – net	$ 20,521	$ 18,084
Current portion of long-term debt	58	27
Accounts payable	752	1,433
Long-term debt	1,125	493
Noncontrolling Interest in Variable Interest Entity	8,217	8,413
FPL [Member]
Customer receivables, net of allowances	11	44	[1]
Current portion of long-term debt	536	354	[2]
Accounts payable	1,318	874	[2]
Long-term debt	$ 17,974	$ 16,882	[2]
Common stock, par value (usd per share)	$ 0	$ 0
Common stock, authorized (in shares)	1,000	1,000
Common stock, issued (in shares)	1,000	1,000
Common stock, outstanding (in shares)	1,000	1,000

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

[2] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

XML

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020		Dec. 31, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)		$ 2,827	$ 2,369		$ 3,388
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization		3,924	4,052		4,216
Nuclear fuel and other amortization		290	263		262
Unrealized losses (gains) on marked to market derivative contracts – net		2,005	533		(108)
Foreign currency transaction losses (gains)		(94)	45		17
Deferred income taxes		436	(78)		258
Cost recovery clauses and franchise fees		(599)	(121)		155
Equity in losses (earnings) of equity method investees		(666)	1,351		(66)
Distributions of earnings from equity method investees		526	456		438
Gains on disposal of businesses, assets and investments – net		(146)	(403)		(461)
Recoverable storm-related costs		(138)	(69)		(180)
Other – net		(326)	189		(141)
Changes in operating assets and liabilities:
Current assets		(1,267)	(364)		123
Noncurrent assets		(324)	(234)		(93)
Current liabilities		1,053	(6)		116
Noncurrent liabilities		52	0		231
Net cash provided by operating activities		7,553	7,983		8,155
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL Segment		(6,626)	(6,477)		(5,560)
Acquisition and capital expenditures of Gulf Power		(782)	(1,012)		(5,165)
Independent power and other investments of NEER		(8,247)	(6,851)		(6,385)
Nuclear fuel purchases		(275)	(245)		(315)
Other capital expenditures		(147)	(25)		(37)
Sale of independent power and other investments of NEER		2,761	1,012		1,316
Proceeds from sale or maturity of securities in special use funds and other investments		4,995	3,916		4,008
Purchases of securities in special use funds and other investments		(5,310)	(4,100)		(4,160)
Other – net		40	83		121
Net cash used in investing activities		(13,591)	(13,699)		(16,177)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt, including premiums and discounts		16,683	12,404		13,905
Retirements of long-term debt		(9,594)	(6,103)		(5,492)
Proceeds from differential membership investors		2,779	3,522		1,604
Net change in commercial paper		(169)	(965)		(234)
Proceeds from other short-term debt		0	2,158		200
Repayments of other short-term debt		(257)	(2,100)		(4,765)
Payments from (to) related parties under a cash sweep and credit support agreement – net		47	(2)		(54)
Issuances of common stock/equity units – net		14			1,494
Payments of Stock Issuance Costs			(92)
Proceeds from sale of noncontrolling interests		65	501		99
Dividends on common stock		(3,024)	(2,743)		(2,408)
Other – net		(737)	(406)		(476)
Net cash provided by financing activities		5,807	6,174		3,873
Effects of currency translation on cash, cash equivalents and restricted cash		1	(20)		4
Net increase (decrease) in cash, cash equivalents and restricted cash		(230)	438		(4,145)
Cash, cash equivalents and restricted cash at beginning of year		1,546	1,108		5,253
Cash, cash equivalents and restricted cash at end of year		1,316	1,546		1,108
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)		1,323	1,432		1,799
Cash paid (received) for income taxes – net		(69)	235		184
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions		4,995	4,445		3,573
Increase in property, plant and equipment related to an acquisition		0	68		0
Decrease in joint venture investments related to an acquisition		0	145		0
FPL [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	[1]	3,206	2,890	[2]	2,519	[2]
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization		2,266	2,526	[3]	2,771	[3]
Nuclear fuel and other amortization		174	167	[3]	178	[3]
Deferred income taxes		752	629	[3]	45	[3]
Cost recovery clauses and franchise fees		(599)	(121)	[3]	155	[3]
Recoverable storm-related costs		(138)	(69)	[3]	(180)	[3]
Other – net		(157)	35	[3]	(5)	[3]
Changes in operating assets and liabilities:
Current assets		(49)	(164)	[3]	(42)	[3]
Noncurrent assets		(114)	(77)	[3]	22	[3]
Current liabilities		20	31	[3]	50	[3]
Noncurrent liabilities		(3)	(31)	[3]	(12)	[3]
Net cash provided by operating activities		5,358	5,816	[3]	5,501	[3]
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures		(7,411)	(7,476)	[3]	(6,290)	[3]
Nuclear fuel purchases		(159)	(203)	[3]	(195)	[3]
Proceeds from sale or maturity of securities in special use funds and other investments		3,308	2,488	[3]	2,729	[3]
Purchases of securities in special use funds and other investments		(3,394)	(2,567)	[3]	(2,854)	[3]
Other – net		15	65	[3]	10	[3]
Net cash used in investing activities		(7,641)	(7,693)	[3]	(6,600)	[3]
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt, including premiums and discounts		2,588	3,003	[3]	2,998	[3]
Retirements of long-term debt		(1,304)	(1,603)	[3]	(200)	[3]
Net change in commercial paper		(169)	(123)	[3]	418	[3]
Proceeds from other short-term debt		0	0	[3]	200	[3]
Capital contributions from NEE		1,700	2,750	[3]	359	[3]
Dividends on common stock		(540)	(2,210)	[3]	(2,620)	[3]
Other – net		(44)	(44)	[3]	(46)	[3]
Net cash provided by financing activities		2,231	1,773	[3]	1,109	[3]
Net increase (decrease) in cash, cash equivalents and restricted cash		(52)	(104)	[3]	10	[3]
Cash, cash equivalents and restricted cash at beginning of year	[3]	160	264		254
Cash, cash equivalents and restricted cash at end of year		108	160	[3]	264	[3]
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)		586	620	[3]	614	[3]
Cash paid (received) for income taxes – net		(1)	105	[3]	584	[3]
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions		1,107	698	[3]	914	[3]
NEE's noncash contribution of a consolidated subsidiary – net		$ 0	$ 0	[3]	$ 4,436	[3]

[1] FPL's comprehensive income is the same as reported net income.

[2] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

[3] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

XML

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY - USD ($) $ in Millions		Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Retained Earnings [Member]	Retained Earnings [Member] Cumulative Effect, Period of Adoption, Adjustment [Member]	[6]	Total common Shareholders' Equity [Member]	Total common Shareholders' Equity [Member] Cumulative Effect, Period of Adoption, Adjustment [Member]	[6]	Noncontrolling Interest [Member]		FPL [Member]		FPL [Member] Common Stock [Member]		FPL [Member] Additional Paid-in Capital [Member]		FPL [Member] Retained Earnings [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Redeemable non-controlling interest, beginning balance		$ 468
Balances (in shares) at Dec. 31, 2018			1,912,000,000
Beginning Balance at Dec. 31, 2018		37,413	$ 19	$ 10,476	$ (188)	$ 23,837			$ 34,144			$ 3,269
BEGINNING BALANCE at Dec. 31, 2018	[1]													$ 21,014		$ 1,373		$ 10,601		$ 9,040
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)		3,388				3,769			3,769					2,519	[2],[3]
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest												(371)
NET INCOME		3,769																		2,519	[1]
Issuances of common stock, net of issuance cost (in shares)			40,000,000
Issuances of common stock/equity units – net				1,470					1,470
Share-based payment activity				164					164
Share-based payment activity (in shares)			4,000,000
Dividends on common stock	[4]					(2,408)			(2,408)
Other comprehensive income (loss)		21			20				20			1
Premium on equity units				(120)					(120)
Other differential membership interests activity				(20)					(20)			1,270
Capital contributions from NEE														359	[5]			359	[1]
Dividends to NEE		2,408												2,620	[5]					(2,620)	[1]
NEE's contribution of a consolidated subsidiary	[1]																	4,525
Other (in shares)			0
Other			$ 1	(15)	(1)	1			(14)			186
ENDING BALANCE at Dec. 31, 2019	[1]													25,797		1,373		15,485		8,939
Ending Balance at Dec. 31, 2019		41,360	$ 20	11,955	(169)	25,199	$ (11)		37,005	$ (11)		4,355
Balance (in shares) at Dec. 31, 2019			1,956,000,000
Increase (Decrease) in Temporary Equity [Roll Forward]
Net income (loss)		(9)
Other differential membership interest activity		29
Other		(1)
Redeemable non-controlling interest, beginning balance at Dec. 31, 2019		487
Increase (Decrease) in Temporary Equity [Roll Forward]
Redeemable non-controlling interest, beginning balance		487
Net income (loss)		2,369				2,919			2,919					2,890	[2],[3]
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest												(546)
NET INCOME		2,919																		2,890	[1]
Issuances of common stock, net of issuance cost (in shares)			0
Issuances of common stock/equity units – net				(92)					(92)
Share-based payment activity				153					153
Share-based payment activity (in shares)			4,000,000
Dividends on common stock	[4]					(2,743)			(2,743)
Other comprehensive income (loss)		74			67				67			7
Impact of disposal of a business					10				10
Premium on equity units				(587)					(587)
Other differential membership interests activity				(36)					(36)			3,809
Sale of noncontrolling interests				(169)					(169)			689
Capital contributions from NEE														2,750	[5]			2,750	[1]
Dividends to NEE		2,743												2,210	[5]					(2,210)	[1]
Other			$ 0	(2)	0	(1)			(3)			102						1	[1]	0	[1]
ENDING BALANCE at Dec. 31, 2020		36,513												29,228	[1]	1,373	[1]	18,236	[1]	9,619	[1]
Ending Balance at Dec. 31, 2020		$ 44,929	$ 20	11,222	(92)	25,363			36,513			8,416		$ 29,228	[7]
Balance (in shares) at Dec. 31, 2020		1,960,000,000	1,960,000,000											1,000
Increase (Decrease) in Temporary Equity [Roll Forward]
Net income (loss)		$ (4)
Other differential membership interest activity		(483)
Redeemable non-controlling interest, beginning balance at Dec. 31, 2020		0
Increase (Decrease) in Temporary Equity [Roll Forward]
Redeemable non-controlling interest, beginning balance		0
Net income (loss)		2,827				3,573			3,573					$ 3,206	[3]
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest												(748)
NET INCOME		3,573																		3,206
Share-based payment activity				132					132
Share-based payment activity (in shares)			3,000,000
Dividends on common stock	[4]					(3,024)			(3,024)
Other comprehensive income (loss)		91			92				92			(1)
Other differential membership interests activity				(26)					(26)			363	[8]
Capital contributions from NEE														1,700				1,700
Dividends to NEE		3,024												540						(540)
Other				(57)		(1)			(58)			192
ENDING BALANCE at Dec. 31, 2021		37,202												33,594		$ 1,373		$ 19,936		$ 12,285
Ending Balance at Dec. 31, 2021		$ 45,424	$ 20	$ 11,271	$ 0	$ 25,911			$ 37,202			$ 8,222		$ 33,594
Balance (in shares) at Dec. 31, 2021		1,963,000,000	1,963,000,000											1,000
Increase (Decrease) in Temporary Equity [Roll Forward]
Net income (loss)		$ 2
Other differential membership interest activity	[8]	243
Redeemable non-controlling interest, beginning balance at Dec. 31, 2021		245
Increase (Decrease) in Temporary Equity [Roll Forward]
Redeemable non-controlling interest, beginning balance		$ 245

[1] 2020 and 2019 amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

[2] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

[3] FPL's comprehensive income is the same as reported net income.

[4] Dividends per share were $1.54, $1.40 and $1.25 for the years ended December 31, 2021, 2020 and 2019, respectively

[5] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

[6] See Note 1 – Measurement of Credit Losses on Financial Instruments.

[7] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

[8] See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

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CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement of Stockholders' Equity [Abstract]
Common stock dividends (in dollars per share)	$ 1.54	$ 1.40	$ 1.25

XML

Summary of Significant Accounting and Reporting Policies

12 Months Ended

Dec. 31, 2021

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. The FPL segment (FPL, excluding Gulf Power, related purchase accounting adjustments and eliminating entries) and the Gulf Power segment (Gulf Power) continued to be operating segments of NEE, as well as FPL, through 2021. 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 Rate Regulation – Base Rates Effective January 2022 through December 2025 below). The merger of FPL and Gulf Power Company was a merger between entities under common control, which required it to be accounted for as if the merger occurred since the inception of common control, with prior periods retrospectively adjusted to furnish comparative information. Accordingly, FPL's consolidated financial statements have been retrospectively adjusted to include the historical results and financial position of the common control merger prior to the merger date. See Note 6 – Merger of FPL and Gulf Power Company.

FPL's principal business is a rate-regulated electric utility which supplies electric service to more than 5.7 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 ownership interests in joint ventures. NEER participates in natural gas, natural gas liquids and oil production primarily through operating and non-operating ownership interests and in pipeline infrastructure through either wholly owned subsidiaries or noncontrolling or joint venture interests. NEER also invests in rate-regulated transmission facilities and transmission lines that connect its electric generation facilities to the electric grid through controlled and consolidated entities.

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 contingent assets and liabilities. Actual results could differ from those estimates.

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 and 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 provide 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 $852 million, $800 million and $838 million in 2021, 2020 and 2019, 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,
	2021		2020		2021		2020
	(millions)
Regulatory assets:
Current:
Early retirement of generation facilities and transmission assets(a)	$	140	$	36	$	140	$	36
Acquisition of purchased power agreements(b)	141		161		141		161
Deferred clause and franchise expenses	698		28		698		28
Other	146		152		132		135
Total	$	1,125	$	377	$	1,111	$	360
Noncurrent:
Early retirement of generation facilities and transmission assets(a)	$	2,233	$	1,438	$	2,233	$	1,438
Acquisition of purchased power agreements(b)	332		473		332		473
Accrued asset removal costs(c)	263		—		263		—
Other	1,750		1,801		1,515		1,488
Total	$	4,578	$	3,712	$	4,343	$	3,399
Regulatory liabilities:
Current:
Deferred clause revenues	$	274	$	215	$	274	$	215
Other	15		30		4		9
Total	$	289	$	245	$	278	$	224
Noncurrent:
Asset retirement obligation regulatory expense difference	$	4,290	$	3,583	$	4,290	$	3,583
Accrued asset removal costs(c)	782		1,206		752		1,179
Deferred taxes	4,561		4,698		4,457		4,594
Other	1,640		1,248		1,554		1,244
Total	$	11,273	$	10,735	$	11,053	$	10,600

______________________

(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)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, 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 underrecovery or overrecovery. Any underrecovered costs or overrecovered revenues are collected from or returned to customers in subsequent periods.

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 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) is 10.60%, with a range of 9.70% to 11.70%. If FPL's earned regulatory ROE falls below 9.70%, FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.70%, any party with standing may seek a review of FPL's retail base rates. If the average 30-year U.S. Treasury rate is 2.49% or greater over a consecutive six-month period, the authorized regulatory ROE will increase to 10.80% with a range of 9.80% to 11.80%. If triggered, the increase in the authorized regulatory ROE will not result in an incremental general base rate increase, but will apply for all other regulatory purposes, including the SoBRA mechanism.

•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 limited to the amortization of $200 million of depreciation reserve surplus during the first year of the 2021 rate agreement.

•FPL is authorized to expand SolarTogether™, a voluntary community solar program that gives certain FPL electric customers an opportunity to participate directly in the expansion of solar energy 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 be able to prospectively adjust base rates after a review by the FPSC.

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.

Base Rates Effective January 2017 through December 2021 – In December 2016, the FPSC issued a final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2016 rate agreement). Key elements of the 2016 rate agreement, which became effective in January 2017, provided for, among other things, the following:

•new retail base rates and charges which resulted in the following increases in annualized retail base revenues:

◦$400 million beginning January 1, 2017;

◦$211 million beginning January 1, 2018; and

◦$200 million beginning April 1, 2019 for a new approximately 1,720 MW natural gas-fired combined-cycle unit in Okeechobee County, Florida that achieved commercial operation on March 31, 2019;

•additional base rate increases in 2018 through 2020 associated with the addition of approximately 1,200 MW of new solar generating capacity that became operational during that timeframe;

•regulatory ROE of 10.55%, with a range of 9.60% to 11.60%;

•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%; and

•an interim cost recovery mechanism for storm restoration costs. See Storm Funds, Storm Reserves and Storm Cost Recovery below.

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, 2021 and 2020, convertible ITCs, net of amortization, were approximately $755 million ($116 million at FPL) and $791 million ($122 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. These new rates are expected to decrease depreciation expense. 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 noncurrent regulatory liabilities at December 31, 2020 on NEE's and FPL's consolidated balance sheets. The FPL segment used available reserve amortization to offset all of the storm restoration costs that were expensed during 2019 through 2021. See Storm Funds, Storm Reserves and Storm Cost Recovery below. 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, 2021 and 2020, NEER's capitalized development costs totaled approximately $831 million and $571 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. In 2019, NEER determined it was no longer moving forward with the construction of a 220 MW wind facility due to unresolved permitting issues. NEE recorded charges of approximately $72 million ($54 million after tax), which are included in taxes other than income taxes and other – net in NEE’s consolidated statements of income for the year ended December 31, 2019, primarily related to the write-off of capitalized construction costs.

Asset Retirement Obligations – 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 subsequently 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 subsequently allocated to expense using a systematic and rational method over the asset's estimated useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense, which is included in depreciation and amortization expense in NEE's consolidated statements of income. Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the asset retirement cost, or income when asset retirement cost is depleted.

Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs – 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, and provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the dismantlement of St. Lucie Unit No. 2 in 2043. These studies also assume that FPL will be storing spent fuel on site pending removal to a United States (U.S.) government facility. 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 $10.2 billion, or $2.4 billion expressed in 2021 dollars. The ultimate costs of decommissioning reflect the application submitted to the U.S. Nuclear Regulatory Commission (NRC) for the extension of 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 2021, 2020 and 2019 fund earnings on decommissioning funds were approximately $173 million, $132 million and $125 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, 2021, FPL's portion of the ultimate cost to dismantle its other generation units is approximately $2.5 billion, or $1.2 billion expressed in 2021 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, 2021 and 2020, NEER's ARO was approximately $1.1 billion and $1.2 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 $9.4 billion, or $2.1 billion expressed in 2021 dollars. The ultimate cost to dismantle NEER's wind and solar facilities is estimated to be approximately $2.0 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, 2021 and 2020, NEE had approximately $677 million ($53 million for FPL) and $441 million ($135 million for FPL), respectively, of restricted cash, of which approximately $677 million ($53 million for FPL) and $374 million ($93 million for FPL), respectively, are included in current other assets and the remaining balances are included in noncurrent 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 $121 million is netted against derivative assets and $172 million is netted against derivative liabilities at December 31, 2021 and $183 million is netted against derivative assets and $136 million is netted against derivative liabilities at December 31, 2020. 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. See also Note 4 – Special Use Funds.

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, 2021, 2020 and 2019, NEE recorded approximately $146 million, $94 million and $32 million of bad debt expense, including credit losses, respectively, which are included in O&M expenses in NEE’s consolidated statements of income. The amount for the year ended December 31, 2021 primarily relates 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 are included in noncurrent other assets on NEE's consolidated balance sheet related to the February 2021 weather event.

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 and property insurance reserve funds (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 and property insurance reserves (storm reserves). 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 2021, 2020 and 2019, FPL’s service area was impacted by hurricanes and tropical storms, which resulted in the recording of incremental storm restoration costs. The FPL segment 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.

Restoration costs associated with multiple storms since 2018 that impacted FPL's customers in the former Gulf Power service area are being collected from northwest Florida customers through a storm damage surcharge through late 2024 and are recorded as regulatory assets. 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. As of December 31, 2020, the balance was $347 million, of which $100 million and $247 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,
		2021		2020
	(years)	(millions)
Goodwill (by reporting unit):
FPL segment:
Florida City Gas		$	292	$	292
Other		9		9
Gulf Power (see Note 6 – Merger of FPL and Gulf Power Company)		2,688		2,688
NEER segment:
Rate-regulated transmission (see Note 6 – GridLiance)		1,206		614
Gas infrastructure		487		487
Customer supply and trading		95		93
Generation assets		56		60
Corporate and Other		11		11
Total goodwill		$	4,844	$	4,254
Other intangible assets not subject to amortization, primarily land easements		$	136	$	135
Other intangible assets subject to amortization:
Purchased power agreements	15	$	507	$	453
Other, primarily transportation contracts and customer lists	23	187		166
Total		694		619
Accumulated amortization		(88)		(61)
Total other intangible assets subject to amortization – net		$	606	$	558

NEE's, including FPL's, goodwill relates to various acquisitions which were accounted for using the purchase method of accounting. Other intangible assets are primarily included in noncurrent other assets on NEE's consolidated balance sheets. NEE's other intangible assets subject to amortization are amortized, primarily on a straight-line basis, over their estimated useful lives. Amortization expense was approximately $25 million, $27 million and $18 million for the years ended December 31, 2021, 2020 and 2019, respectively, and is expected to be approximately $16 million, $16 million, $18 million, $16 million and $16 million for 2022, 2023, 2024, 2025 and 2026, 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, 2022. 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, 2022 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.

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 $3,780 million ($3,723 million for FPL) and $3,949 million ($3,890 million for FPL) at December 31, 2021 and 2020, respectively, and is being amortized in accordance with the regulatory treatment over the estimated lives of the assets or liabilities for which the deferred tax amount was initially recognized.

Production tax credits (PTCs) are recognized as wind energy is generated and sold based on a per kWh rate prescribed in applicable federal and state statutes and are recorded as a reduction of current income taxes payable, unless limited by tax law in which instance they are recorded as deferred tax assets. NEER recognizes ITCs as a reduction to income tax expense when the related energy property is placed into service. FPL recognizes ITCs as a reduction to income tax expense over the depreciable life of the related energy property. At December 31, 2021 and 2020, FPL’s accumulated deferred ITCs were approximately $1,054 million and $753 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, 2021, NEE had unrecognized tax benefits of approximately $125 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 and solar generation facilities, with generating capacity totaling approximately 11,226 MW and 1,894 MW, respectively, and battery storage capacity in operation or under construction totaling 220 MW at December 31, 2021, to third-party investors. NEE retains a controlling interest in the entities and therefore presents the Class B member interests as noncontrolling interests. Noncontrolling interests represents the portion of net assets in consolidated entities that are not owned by NEE and are reported as a component of equity in NEE’s consolidated balance sheet. The third-party investors are allocated earnings, tax attributes and cash flows in accordance with the respective limited liability company agreements. Those economics are allocated primarily to the third-party investors until they receive a targeted return (the flip date) and thereafter to NEE. NEE has the right to call the third-party interests at specified amounts if and when the flip date occurs. NEE has determined the allocation of economics between the controlling party and third-party investor should not follow the respective ownership percentages for each wind and solar project but rather the hypothetical liquidation of book value (HLBV) method based on the governing provisions in each respective limited liability company agreement. Under the HLBV method, the amounts of income and loss attributable to the noncontrolling interest reflects changes in the amount the owners would hypothetically receive at each balance sheet date under the respective liquidation provisions, assuming the net assets of these entities were liquidated at the recorded amounts, after taking into account any capital transactions, such as contributions and distributions, between the entities and the owners. At the point in time that the third-party investor, in hypothetical liquidation, would achieve its targeted return, NEE attributes the additional hypothetical proceeds to the Class B membership interests based on the call price. A loss attributable to noncontrolling interest on NEE’s consolidated statements of income represents earnings attributable to NEE.

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 sheet as of December 31, 2021. These contingencies are expected to be resolved in 2022.

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 included 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 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 are currently under construction with expected in-service dates in the first half of 2022. Total cash proceeds for these two separate transactions totaled approximately $1.7 billion, subject to working capital and other adjustments. NEER will continue to consolidate the three projects currently under construction for accounting purposes. 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) is reflected in the gains on disposal of businesses/assets – net in NEE’s consolidated statements of income for the year ended December 31, 2021. In connection with the three facilities currently 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. The contract liabilities relate 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 is contingent on the enactment of a solar PTC by a specified date in 2022. The contract liabilities associated with the sale proceeds and the differential membership interests are also subject to the three facilities under construction achieving commercial operations by specified dates in the first half of 2022. The contract liabilities will be reversed and the sale recognized for accounting purposes if the contingencies are resolved in 2022. Otherwise, NextEra Energy Resources may be required to return proceeds related to differential membership interests and/or repurchase the facilities for up to $668 million. In addition, NextEra Energy Resources is responsible to pay for all construction costs related to the portfolio. At December 31, 2021, approximately $970 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 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 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 December 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, in December 2020, 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) 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. In 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 at December 31, 2020. In connection with the solar-plus-storage facility transaction, approximately $155 million of cash received was recorded as a contract liability, which is included in current other liabilities on NEE's consolidated balance sheet at December 31, 2020. The solar-plus-storage facility achieved commercial operations in June 2021 and 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.

In 2019, subsidiaries of NextEra Energy Resources completed the sale of ownership interests in three wind generation facilities and three solar generation facilities, including noncontrolling interests in two of the solar facilities, located in the Midwest and West regions of the U.S. with a total net generating capacity of 611 MW to a NEP subsidiary for cash proceeds of approximately $1.0 billion, plus working capital of $12 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 $341 million ($259 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2019, which is included in gains on disposal of businesses/assets – net, and noncontrolling interests of approximately $118 million were recorded on NEE's consolidated balance sheet.

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Revenue from Contracts with Customers

12 Months Ended

Dec. 31, 2021

Revenue from Contract with Customer [Abstract]

Revenue from Contracts with Customers

Revenue from Contracts with Customers

Revenue is recognized when control of the promised goods or services is transferred to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. The promised goods or services in the majority of NEE’s contracts with customers is, at FPL, for the delivery of electricity based on tariff rates approved by the FPSC and, at NEER, for the delivery of energy commodities and the availability of electric capacity and electric transmission.

FPL and NEER generate substantially all of NEE’s operating revenues, which primarily include revenues from contracts with customers, as well as derivative and lease transactions at NEER. For the vast majority of contracts with customers, NEE believes that the obligation to deliver energy, capacity or transmission is satisfied over time as the customer simultaneously receives and consumes benefits as NEE performs. In 2021, 2020 and 2019, NEE’s revenue from contracts with customers was approximately $18.8 billion ($14.1 billion at FPL), $17.0 billion ($13.0 billion at FPL) and $17.5 billion ($13.6 billion at FPL), respectively. NEE's and FPL's receivables are primarily associated with revenues earned from contracts with customers, as well as derivative and lease transactions at NEER, and consist of both billed and unbilled amounts, which are recorded in customer receivables and other receivables on NEE's and FPL's consolidated balance sheets. Receivables represent unconditional rights to consideration and reflect the differences in timing of revenue recognition and cash collections. For substantially all of NEE's and FPL's receivables, regardless of the type of revenue transaction from which the receivable originated, customer and counterparty credit risk is managed in the same manner and the terms and conditions of payment are similar. During 2021, NEER did not recognize approximately $180 million of revenue related to reimbursable expenses from a counterparty that are deemed not probable of collection. These reimbursable expenses arose from the impacts of the February 2021 weather event. These determinations were made based on assessments of the counterparty's creditworthiness and NEER's ability to collect.

FPL – FPL’s revenues are derived primarily from tariff-based sales that result from providing electricity to retail customers in Florida with no defined contractual term. Electricity sales to retail customers account for approximately 90% of FPL’s 2021 operating revenues, the majority of which are to residential customers. FPL’s retail customers receive a bill monthly based on the amount of monthly kWh usage with payment due monthly. For these types of sales, FPL recognizes revenue as electricity is delivered and billed to customers, as well as an estimate for electricity delivered and not yet billed. The billed and unbilled amounts represent the value of electricity delivered to the customer. At December 31, 2021 and 2020, FPL's unbilled revenues amounted to approximately $583 million and $454 million, respectively, and are included in customer receivables on NEE’s and FPL’s consolidated balance sheets. Certain contracts with customers contain a fixed price which primarily relate to certain power purchase agreements with maturity dates through 2041. As of December 31, 2021, FPL expects to record approximately $400 million of revenues related to the fixed capacity price components of such contracts over the remaining terms of the related

contracts as the capacity is provided. These contracts also contain a variable price component for energy usage which FPL recognizes as revenue as the energy is delivered based on rates stipulated in the respective contracts.

NEER – NEER’s revenue from contracts with customers is derived primarily from the sale of energy commodities, electric capacity and electric transmission. For these types of sales, NEER recognizes revenue as energy commodities are delivered and as electric capacity and electric transmission are made available, consistent with the amounts billed to customers based on rates stipulated in the respective contracts as well as an accrual for amounts earned but not yet billed. The amounts billed and accrued represent the value of energy or transmission delivered and/or the capacity of energy or transmission available to the customer. Revenues yet to be earned under these contracts, which have maturity dates ranging from 2022 to 2053, will vary based on the volume of energy or transmission delivered and/or available. NEER’s customers typically receive bills monthly with payment due within 30 days. Certain contracts with customers contain a fixed price which primarily relate to electric capacity sales associated with independent system operator annual auctions through 2025 and certain power purchase agreements with maturity dates through 2034. As of December 31, 2021, NEER expects to record approximately $735 million of revenues related to the fixed price components of such contracts over the remaining terms of the related contracts as the capacity is provided.

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Derivative Instruments

12 Months Ended

Dec. 31, 2021

Derivative Instruments [Abstract]

Derivative Instruments

Derivative Instruments

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, as well as interest rate and foreign currency exchange rate risk associated primarily with outstanding and expected future debt issuances and borrowings, and to optimize the value of NEER's power generation and gas infrastructure assets. NEE and FPL do not utilize hedge accounting for their cash flow and fair value hedges.

With respect to commodities related to NEE's competitive energy business, NEER employs risk management procedures to conduct its activities related to optimizing the value of its power generation and gas infrastructure assets, providing full energy and capacity requirements services primarily to distribution utilities, and engaging in power and fuel marketing and trading activities to take advantage of expected future favorable price movements and changes in the expected volatility of prices in the energy markets. These risk management activities involve the use of derivative instruments executed within prescribed limits to manage the risk associated with fluctuating commodity prices. Transactions in derivative instruments are executed on recognized exchanges or via the over-the-counter (OTC) markets, depending on the most favorable credit terms and market execution factors. For NEER's power generation and gas infrastructure assets, derivative instruments are used to hedge all or a portion of the expected output of these assets. These hedges are designed to reduce the effect of adverse changes in the wholesale forward commodity markets associated with NEER's power generation and gas infrastructure assets. With regard to full energy and capacity requirements services, NEER is required to vary the quantity of energy and related services based on the load demands of the customers served. For this type of transaction, derivative instruments are used to hedge the anticipated electricity quantities required to serve these customers and reduce the effect of unfavorable changes in the forward energy markets. Additionally, NEER takes positions in energy markets based on differences between actual forward market levels and management's view of fundamental market conditions, including supply/demand imbalances, changes in traditional flows of energy, changes in short- and long-term weather patterns and anticipated regulatory and legislative outcomes. NEER uses derivative instruments to realize value from these market dislocations, subject to strict risk management limits around market, operational and credit exposure.

Derivative instruments, when required to be marked to market, are recorded on NEE's and FPL's consolidated balance sheets as either an asset or liability measured at fair value. At FPL, substantially all changes in the derivatives' fair value are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the applicable fuel and purchased power cost recovery clause (fuel clause). For NEE's non-rate regulated operations, predominantly NEER, essentially all changes in the derivatives' fair value for power purchases and sales, fuel sales and trading activities are recognized on a net basis in operating revenues and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's consolidated statements of income. Settlement gains and losses are included within the line items in the consolidated statements of income to which they relate. Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the consolidated statements of income. For commodity derivatives, NEE believes that, where offsetting positions exist at the same location for the same time, the transactions are considered to have been netted and therefore physical delivery has been deemed not to have occurred for financial reporting purposes. Settlements related to derivative instruments are primarily recognized in net cash provided by operating activities in NEE's and FPL's consolidated statements of cash flows.

For interest rate and foreign currency derivative instruments, all changes in the derivatives' fair value, as well as the transaction gain or loss on foreign denominated debt, are recognized in interest expense and the equity method investees' related activity is recognized in equity in earnings (losses) of equity method investees in NEE's consolidated statements of income. In addition, for the years ended December 31, 2020 and 2019, NEE reclassified from AOCI approximately $26 million ($6 million after tax), of which $23 million was reclassified to gains on disposal of businesses/assets – net (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests) with the balance to interest expense, and $11 million ($8 million after tax) to

interest expense, respectively, because it became probable that related future transactions being hedged would not occur. At December 31, 2021, NEE's AOCI included amounts related to discontinued interest rate cash flow hedges with expiration dates through March 2035 and foreign currency cash flow hedges with expiration dates through September 2030. Approximately $6 million of net losses included in AOCI at December 31, 2021 are expected to be reclassified into earnings within the next 12 months as the principal and/or interest payments are made. Such amounts assume no change in scheduled principal payments.

Fair Value Measurements of Derivative Instruments – The fair value of assets and liabilities are determined using either unadjusted quoted prices in active markets (Level 1) or pricing inputs that are observable (Level 2) whenever that information is available and using unobservable inputs (Level 3) to estimate fair value only when relevant observable inputs are not available. NEE and FPL use several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those assets and liabilities that are measured at fair value on a recurring basis. NEE's and FPL's assessment of the significance of any particular input to the fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Non-performance risk, including the consideration of a credit valuation adjustment, is also considered in the determination of fair value for all assets and liabilities measured at fair value.

NEE and FPL measure the fair value of commodity contracts using a combination of market and income approaches utilizing prices observed on commodities exchanges and in the OTC markets, or through the use of industry-standard valuation techniques, such as option modeling or discounted cash flows techniques, incorporating both observable and unobservable valuation inputs. The resulting measurements are the best estimate of fair value as represented by the transfer of the asset or liability through an orderly transaction in the marketplace at the measurement date.

Most exchange-traded derivative assets and liabilities are valued directly using unadjusted quoted prices. For exchange-traded derivative assets and liabilities where the principal market is deemed to be inactive based on average daily volumes and open interest, the measurement is established using settlement prices from the exchanges, and therefore considered to be valued using other observable inputs.

NEE, through its subsidiaries, including FPL, also enters into OTC commodity contract derivatives. The majority of these contracts are transacted at liquid trading points, and the prices for these contracts are verified using quoted prices in active markets from exchanges, brokers or pricing services for similar contracts.

NEE, through NEER, also enters into full requirements contracts, which, in most cases, meet the definition of derivatives and are measured at fair value. These contracts typically have one or more inputs that are not observable and are significant to the valuation of the contract. In addition, certain exchange and non-exchange traded derivative options at NEE have one or more significant inputs that are not observable, and are valued using industry-standard option models.

In all cases where NEE and FPL use significant unobservable inputs for the valuation of a commodity contract, consideration is given to the assumptions that market participants would use in valuing the asset or liability. The primary input to the valuation models for commodity contracts is the forward commodity curve for the respective instruments. Other inputs include, but are not limited to, assumptions about market liquidity, volatility, correlation and contract duration as more fully described below in Significant Unobservable Inputs Used in Recurring Fair Value Measurements. In instances where the reference markets are deemed to be inactive or do not have transactions for a similar contract, the derivative assets and liabilities may be valued using significant other observable inputs and potentially significant unobservable inputs. In such instances, the valuation for these contracts is established using techniques including extrapolation from or interpolation between actively traded contracts, or estimated basis adjustments from liquid trading points. NEE and FPL regularly evaluate and validate the inputs used to determine fair value by a number of methods, consisting of various market price verification procedures, including the use of pricing services and multiple broker quotes to support the market price of the various commodities. In all cases where there are assumptions and models used to generate inputs for valuing derivative assets and liabilities, the review and verification of the assumptions, models and changes to the models are undertaken by individuals that are independent of those responsible for estimating fair value.

NEE uses interest rate contracts and foreign currency contracts to mitigate and adjust interest rate and foreign currency exchange exposure related primarily to certain outstanding and expected future debt issuances and borrowings when deemed appropriate based on market conditions or when required by financing agreements. NEE estimates the fair value of these derivatives using an income approach based on a discounted cash flows valuation technique utilizing the net amount of estimated future cash inflows and outflows related to the agreements.

The tables below present NEE's and FPL's gross derivative positions at December 31, 2021 and December 31, 2020, as required by disclosure rules. However, the majority of the underlying contracts are subject to master netting agreements and generally would not be contractually settled on a gross basis. Therefore, the tables below also present the derivative positions on a net basis, which reflect the offsetting of positions of certain transactions within the portfolio, the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral, as well as the location of the net derivative position on the consolidated balance sheets.

	December 31, 2021
	Level 1		Level 2		Level 3		Netting(a)		Total
	(millions)
Assets:
NEE:
Commodity contracts	$	1,896	$	5,082	$	1,401	$	(6,622)	$	1,757
Interest rate contracts	$	—	$	106	$	—	$	(30)	76
Foreign currency contracts	$	—	$	8	$	—	$	(17)	(9)
Total derivative assets									$	1,824
FPL – commodity contracts	$	—	$	3	$	13	$	(3)	$	13
Liabilities:
NEE:
Commodity contracts	$	2,571	$	4,990	$	1,231	$	(6,594)	$	2,198
Interest rate contracts	$	—	$	739	$	—	$	(30)	709
Foreign currency contracts	$	—	$	86	$	—	$	(17)	69
Total derivative liabilities									$	2,976
FPL – commodity contracts	$	—	$	8	$	5	$	(3)	$	10
Net fair value by NEE balance sheet line item:
Current derivative assets(b)									$	689
Noncurrent derivative assets(c)									1,135
Total derivative assets									$	1,824
Current derivative liabilities(d)									$	1,263
Noncurrent derivative liabilities(e)									1,713
Total derivative liabilities									$	2,976
Net fair value by FPL balance sheet line item:
Current other assets									$	13
Current other liabilities									$	9
Noncurrent other liabilities									1
Total derivative liabilities									$	10

______________________

(a)Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the consolidated balance sheets and are recorded in customer receivables – net and accounts payable, respectively.

(b)Reflects the netting of approximately $150 million in margin cash collateral received from counterparties.

(c)Reflects the netting of approximately $56 million in margin cash collateral received from counterparties.

(d)Reflects the netting of approximately $6 million in margin cash collateral paid to counterparties.

(e)Reflects the netting of approximately $172 million in margin cash collateral paid to counterparties.

	December 31, 2020
	Level 1		Level 2		Level 3		Netting(a)		Total
	(millions)
Assets:
NEE:
Commodity contracts	$	919	$	1,881	$	1,679	$	(2,325)	$	2,154
Interest rate contracts	$	—	$	81	$	—	$	(41)	40
Foreign currency contracts	$	—	$	57	$	—	$	(34)	23
Total derivative assets									$	2,217
FPL – commodity contracts	$	—	$	1	$	2	$	—	$	3
Liabilities:
NEE:
Commodity contracts	$	1,004	$	1,468	$	305	$	(2,277)	$	500
Interest rate contracts	$	—	$	1,042	$	—	$	(41)	1,001
Foreign currency contracts	$	—	$	43	$	—	$	(34)	9
Total derivative liabilities									$	1,510
FPL – commodity contracts	$	—	$	—	$	3	$	—	$	3
Net fair value by NEE balance sheet line item:
Current derivative assets									$	570
Noncurrent derivative assets(b)									1,647
Total derivative assets									$	2,217
Current derivative liabilities(c)									$	311
Noncurrent derivative liabilities									1,199
Total derivative liabilities									$	1,510
Net fair value by FPL balance sheet line item:
Current other assets									$	3
Current other liabilities									$	2
Noncurrent other liabilities									1
Total derivative liabilities									$	3

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(a)Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the consolidated balance sheets and are recorded in customer receivables – net and accounts payable, respectively.

(b)Reflects the netting of approximately $184 million in margin cash collateral received from counterparties.

(c)Reflects the netting of approximately $136 million in margin cash collateral paid to counterparties.

At December 31, 2021 and 2020, NEE had approximately $56 million and $6 million (none at FPL), respectively, in margin cash collateral received from counterparties that was not offset against derivative assets in the above presentation. These amounts are included in current other liabilities on NEE's consolidated balance sheets. Additionally, at December 31, 2021 and 2020, NEE had approximately $673 million and $315 million (none at FPL), respectively, in margin cash collateral paid to counterparties that was not offset against derivative assets or liabilities in the above presentation. These amounts are included in current other assets on NEE's consolidated balance sheets.

Significant Unobservable Inputs Used in Recurring Fair Value Measurements – The valuation of certain commodity contracts requires the use of significant unobservable inputs. All forward price, implied volatility, implied correlation and interest rate inputs used in the valuation of such contracts are directly based on third-party market data, such as broker quotes and exchange settlements, when that data is available. If third-party market data is not available, then industry standard methodologies are used to develop inputs that maximize the use of relevant observable inputs and minimize the use of unobservable inputs. Observable inputs, including some forward prices, implied volatilities and interest rates used for determining fair value are updated daily to reflect the best available market information. Unobservable inputs which are related to observable inputs, such as illiquid portions of forward price or volatility curves, are updated daily as well, using industry standard techniques such as interpolation and extrapolation, combining observable forward inputs supplemented by historical market and other relevant data. Other unobservable inputs, such as implied correlations, block-to-hourly price shaping, customer migration rates from full requirements contracts and some implied volatility curves, are modeled using proprietary models based on historical data and industry standard techniques.

The significant unobservable inputs used in the valuation of NEE's commodity contracts categorized as Level 3 of the fair value hierarchy at December 31, 2021 are as follows:

Transaction Type	Fair Value at December 31, 2021				Valuation Technique(s)	Significant Unobservable Inputs	Range			Weighted-average(a)
	Assets		Liabilities
	(millions)
Forward contracts – power	$	433	$	204	Discounted cash flow	Forward price (per MWh(b))	$(5)	—	$140	$37
Forward contracts – gas	191		31		Discounted cash flow	Forward price (per MMBtu(c))	$2	—	$15	$3
Forward contracts – congestion	29		8		Discounted cash flow	Forward price (per MWh(b))	$(10)	—	$45	$—
Options – power	52		(1)		Option models	Implied correlations	32%	—	86%	52%
						Implied volatilities	8%	—	368%	81%
Options – primarily gas	356		347		Option models	Implied correlations	32%	—	86%	52%
						Implied volatilities	17%	—	295%	36%
Full requirements and unit contingent contracts	200		566		Discounted cash flow	Forward price (per MWh(b))	$2	—	$308	$64
						Customer migration rate(d)	—%	—	19%	2%
Forward contracts – other	140		76
Total	$	1,401	$	1,231

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(a)Unobservable inputs were weighted by volume.

(b)Megawatt-hours

(c)One million British thermal units

(d)Applies only to full requirements contracts.

The sensitivity of NEE's fair value measurements to increases (decreases) in the significant unobservable inputs is as follows:

Significant Unobservable Input	Position	Impact on Fair Value Measurement
Forward price	Purchase power/gas	Increase (decrease)
	Sell power/gas	Decrease (increase)
Implied correlations	Purchase option	Decrease (increase)
	Sell option	Increase (decrease)
Implied volatilities	Purchase option	Increase (decrease)
	Sell option	Decrease (increase)
Customer migration rate	Sell power(a)	Decrease (increase)

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(a)Assumes the contract is in a gain position.

The reconciliation of changes in the fair value of derivatives that are based on significant unobservable inputs is as follows:

	Years Ended December 31,
	2021				2020				2019
	NEE		FPL		NEE		FPL		NEE		FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year	$	1,374	$	(1)	$	1,207	$	(8)	$	647	$	(36)
Realized and unrealized gains (losses):
Included in earnings(a)	(1,488)		—		547		—		923		—
Included in other comprehensive income (loss)(b)	—		—		1		—		5		—
Included in regulatory assets and liabilities	8		8		2		2		1		1
Purchases	243		—		191		—		141		—
Sales(c)	—		—		114		—		—		—
Settlements	259		1		(562)		6		(356)		25
Issuances	(196)		—		(123)		—		(87)		—
Transfers in(d)	2		—		18		(1)		(5)		—
Transfers out(d)	(32)		—		(21)		—		(62)		2
Fair value of net derivatives based on significant unobservable inputs at December 31	$	170	$	8	$	1,374	$	(1)	$	1,207	$	(8)
Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date(e)	$	(924)	$	—	$	317	$	—	$	611	$	—

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(a)For the years ended December 31, 2021, 2020 and 2019, realized and unrealized gains (losses) of approximately $(1,488) million, $569 million and $956 million are included in the consolidated statements of income in operating revenues and the balance is included in interest expense.

(b)Included in net unrealized gains (losses) on foreign currency translation in the consolidated statements of comprehensive income.

(c)See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

(d)Transfers into Level 3 were a result of decreased observability of market data. Transfers from Level 3 to Level 2 were a result of increased observability of market data.

(e)For the years ended December 31, 2021, 2020 and 2019, unrealized gains (losses) of approximately $(924) million, $317 million and $638 million are included in the consolidated statements of income in operating revenues and the balance is included in interest expense.

Income Statement Impact of Derivative Instruments – Gains (losses) related to NEE's derivatives are recorded in NEE's consolidated statements of income as follows:

	Years Ended December 31,
	2021		2020		2019
	(millions)
Commodity contracts(a) – operating revenues	$	(2,710)	$	352	$	762
Foreign currency contracts – interest expense	(89)		8		(7)
Interest rate contracts – interest expense	264		(421)		(699)
Losses reclassified from AOCI:
Interest rate contracts(b)	(7)		(35)		(32)
Foreign currency contracts – interest expense	(3)		(3)		(4)
Total	$	(2,545)	$	(99)	$	20

______________________

(a)For the years ended December 31, 2021, 2020 and 2019, FPL recorded gains of approximately $7 million, $6 million and $9 million, respectively, related to commodity contracts as regulatory liabilities on its consolidated balance sheets.

(b)For the year ended December 31, 2020, approximately $23 million was reclassified to gains on disposal of businesses/assets – net (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests); remaining balances were reclassified to interest expense on NEE's consolidated statements of income.

Notional Volumes of Derivative Instruments – The following table represents net notional volumes associated with derivative instruments that are required to be reported at fair value in NEE's and FPL's consolidated financial statements. The table includes significant volumes of transactions that have minimal exposure to commodity price changes because they are variably priced agreements. These volumes are only an indication of the commodity exposure that is managed through the use of derivatives. They do not represent net physical asset positions or non-derivative positions and the related hedges, nor do they represent NEE's and FPL's net economic exposure, but only the net notional derivative positions that fully or partially hedge the related asset positions. NEE and FPL had derivative commodity contracts for the following net notional volumes:

	December 31, 2021				December 31, 2020
Commodity Type	NEE		FPL		NEE		FPL
	(millions)
Power	(103)	MWh	—		(90)	MWh	—
Natural gas	(1,290)	MMBtu	91	MMBtu	(607)	MMBtu	87	MMBtu
Oil	(33)	barrels	—		(6)	barrels	—

At December 31, 2021 and 2020, NEE had interest rate contracts with a notional amount of approximately $11.2 billion and a net notional amount of approximately $10.5 billion, respectively, and foreign currency contracts with a notional amount of approximately $1.0 billion and $1.0 billion, respectively.

Credit-Risk-Related Contingent Features – Certain derivative instruments contain credit-risk-related contingent features including, among other things, the requirement to maintain an investment grade credit rating from specified credit rating agencies and certain financial ratios, as well as credit-related cross-default and material adverse change triggers. At December 31, 2021 and 2020, the aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately $4.1 billion ($12 million for FPL) and $1.9 billion ($3 million for FPL), respectively.

If the credit-risk-related contingent features underlying these derivative agreements were triggered, certain subsidiaries of NEE, including FPL, could be required to post collateral or settle contracts according to contractual terms which generally allow netting of contracts in offsetting positions. Certain derivative contracts contain multiple types of credit-related triggers. To the extent these contracts contain a credit ratings downgrade trigger, the maximum exposure is included in the following credit ratings collateral posting requirements. If FPL's and NEECH's credit ratings were downgraded to BBB/Baa2 (a three level downgrade for FPL and a one level downgrade for NEECH from the current lowest applicable rating), applicable NEE subsidiaries would be required to post collateral such that the total posted collateral would be approximately $645 million (none at FPL) and $80 million (none at FPL) at December 31, 2021 and 2020, respectively. If FPL's and NEECH's credit ratings were downgraded to below investment grade, applicable NEE subsidiaries would be required to post additional collateral such that the total posted collateral would be approximately $2.7 billion ($35 million at FPL) and $1.2 billion ($75 million at FPL) at December 31, 2021 and 2020, respectively. Some derivative contracts do not contain credit ratings downgrade triggers, but do contain provisions that require certain financial measures be maintained and/or have credit-related cross-default triggers. In the event these provisions were triggered, applicable NEE subsidiaries could be required to post additional collateral of up to approximately $1,040 million ($145 million at FPL) and $880 million ($75 million at FPL) at December 31, 2021 and 2020, respectively.

Collateral related to derivatives may be posted in the form of cash or credit support in the normal course of business. At December 31, 2021 and 2020, applicable NEE subsidiaries have posted approximately $84 million (none at FPL) and $2 million (none at FPL), respectively, in cash and $1,060 million (none at FPL) and $66 million (none at FPL), respectively, in the form of letters of credit each of which could be applied toward the collateral requirements described above. FPL and NEECH have capacity under their credit facilities generally in excess of the collateral requirements described above that would be available to support, among other things, derivative activities. Under the terms of the credit facilities, maintenance of a specific credit rating is not a condition to drawing on these credit facilities, although there are other conditions to drawing on these credit facilities.

Additionally, some contracts contain certain adequate assurance provisions whereby a counterparty may demand additional collateral based on subjective events and/or conditions. Due to the subjective nature of these provisions, NEE and FPL are unable to determine an exact value for these items and they are not included in any of the quantitative disclosures above.

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Non-Derivative Fair Value Measurements

12 Months Ended

Dec. 31, 2021

Fair Value Disclosures [Abstract]

Non-Derivative Fair Value Measurements

Non-Derivative Fair Value Measurements

Non-derivative fair value measurements consist of NEE’s and FPL’s cash equivalents and restricted cash equivalents, special use funds and other investments. The fair value of these financial assets is determined by using the valuation techniques and inputs as described in Note 3 – Fair Value Measurements of Derivative Instruments as well as below.

Cash Equivalents and Restricted Cash Equivalents – NEE and FPL hold investments in money market funds. The fair value of these funds is estimated using a market approach based on current observable market prices.

Special Use Funds and Other Investments – NEE and FPL hold primarily debt and equity securities directly, as well as indirectly through commingled funds. Substantially all directly held equity securities are valued at their quoted market prices. For directly held debt securities, multiple prices and price types are obtained from pricing vendors whenever possible, which enables cross-provider validations. A primary price source is identified based on asset type, class or issue of each security. Commingled funds, which are similar to mutual funds, are maintained by banks or investment companies and hold certain investments in accordance with a stated set of objectives. The fair value of commingled funds is primarily derived from the quoted prices in active markets of the underlying securities. Because the fund shares are offered to a limited group of investors, they are not considered to be traded in an active market.

Recurring Non-Derivative Fair Value Measurements – NEE's and FPL's financial assets and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows:

	December 31, 2021
	Level 1		Level 2			Level 3		Total
	(millions)
Assets:
Cash equivalents and restricted cash equivalents:(a)
NEE – equity securities	$	176	$	—		$	—	$	176
FPL – equity securities	$	58	$	—		$	—	$	58
Special use funds:(b)
NEE:
Equity securities	$	2,538	$	2,973	(c)	$	—	$	5,511
U.S. Government and municipal bonds	$	770	$	75		$	—	$	845
Corporate debt securities	$	7	$	955		$	—	$	962
Mortgage-backed securities	$	—	$	431		$	—	$	431
Other debt securities	$	2	$	265		$	—	$	267
FPL:
Equity securities	$	862	$	2,690	(c)	$	—	$	3,552
U.S. Government and municipal bonds	$	624	$	44		$	—	$	668
Corporate debt securities	$	6	$	720		$	—	$	726
Mortgage-backed securities	$	—	$	313		$	—	$	313
Other debt securities	$	2	$	225		$	—	$	227
Other investments:(d)
NEE:
Equity securities	$	70	$	2		$	—	$	72
Debt securities	$	111	$	162		$	12	$	285
FPL – equity securities	$	13	$	—		$	—	$	13

______________________

(a)Includes restricted cash equivalents of approximately $56 million ($53 million for FPL) in current other assets on the consolidated balance sheets.

(b)Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below.

(c)Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

(d)Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets.

	December 31, 2020
	Level 1		Level 2			Level 3		Total
	(millions)
Assets:
Cash equivalents and restricted cash equivalents:(a)
NEE – equity securities	$	742	$	—		$	—	$	742
FPL – equity securities	$	137	$	—		$	—	$	137
Special use funds:(b)
NEE:
Equity securities	$	2,237	$	2,489	(c)	$	—	$	4,726
U.S. Government and municipal bonds	$	590	$	127		$	—	$	717
Corporate debt securities	$	1	$	870		$	—	$	871
Mortgage-backed securities	$	—	$	422		$	—	$	422
Other debt securities	$	—	$	124		$	—	$	124
FPL:
Equity securities	$	752	$	2,260	(c)	$	—	$	3,012
U.S. Government and municipal bonds	$	449	$	87		$	—	$	536
Corporate debt securities	$	—	$	627		$	—	$	627
Mortgage-backed securities	$	—	$	335		$	—	$	335
Other debt securities	$	—	$	119		$	—	$	119
Other investments:(d)
NEE:
Equity securities	$	62	$	—		$	—	$	62
Debt securities	$	91	$	127		$	—	$	218
FPL - equity securities	$	12	$	—		$	—	$	12

______________________

(a)Includes restricted cash equivalents of approximately $111 million ($91 million for FPL) in current other assets and $42 million ($42 million for FPL) in noncurrent other assets on the consolidated balance sheets.

(b)Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below.

(c)Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

(d)Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets.

Contingent Consideration – At December 31, 2021, NEER had approximately $261 million of contingent consideration liabilities which are included in noncurrent other liabilities on NEE's consolidated balance sheet. The liabilities relate to contingent consideration for the completion of capital expenditures for future development projects in connection with the acquisition of GridLiance Holdco, LP and GridLiance GP, LLC (see Note 6 – GridLiance). NEECH guarantees the contingent consideration obligations under the GridLiance acquisition agreements. Significant inputs and assumptions used in the fair value measurement, some of which are Level 3 and require judgement, include the projected timing and amount of future cash flows, estimated probability of completing future development projects as well as discount rates.

Fair Value of Financial Instruments Recorded at Other than Fair Value – The carrying amounts of commercial paper and other short-term debt approximate their fair values. The carrying amounts and estimated fair values of other financial instruments recorded at other than fair value are as follows:

	December 31, 2021					December 31, 2020
	Carrying Amount		Estimated Fair Value			Carrying Amount		Estimated Fair Value
	(millions)
NEE:
Special use funds(a)	$	906	$	907		$	919	$	920
Other investments(b)	$	102	$	102		$	29	$	29
Long-term debt, including current portion	$	52,745	$	57,290	(c)	$	46,082	$	51,525	(c)
FPL:
Special use funds(a)	$	672	$	672		$	718	$	719
Long-term debt, including current portion	$	18,510	$	21,379	(c)	$	17,236	$	21,178	(c)

______________________

(a)Primarily represents investments accounted for under the equity method and loans not measured at fair value on a recurring basis (Level 2).

(b)Included in noncurrent other assets on NEE's consolidated balance sheets.

(c)At December 31, 2021 and 2020, substantially all is Level 2 for NEE and FPL.

Special Use Funds – The special use funds noted above and those carried at fair value (see Recurring Non-Derivative Fair Value Measurements above) consist of NEE's nuclear decommissioning fund assets of approximately $8,846 million and $7,703 million at December 31, 2021 and 2020, respectively, ($6,082 million and $5,271 million, respectively, for FPL) and FPL's storm fund assets of $76 million and $76 million at December 31, 2021 and 2020, respectively. The investments held in the special use funds consist of equity and available for sale debt securities which are primarily carried at estimated fair value. The amortized cost of debt securities is approximately $2,438 million and $2,009 million at December 31, 2021 and 2020, respectively ($1,877 million and $1,521 million, respectively, for FPL). Debt securities included in the nuclear decommissioning funds have a weighted-average maturity at December 31, 2021 of approximately eight years at both NEE and FPL. FPL's storm fund primarily consists of debt securities with a weighted-average maturity at December 31, 2021 of approximately one year. The cost of securities sold is determined using the specific identification method.

Effective January 1, 2020, NEE and FPL adopted an accounting standards update that provides a modified version of the other-than-temporary impairment model for debt securities. The new available for sale debt security impairment model no longer allows consideration of the length of time during which the fair value has been less than its amortized cost basis when determining whether a credit loss exists. Credit losses are required to be presented as an allowance rather than as a write-down of securities not intended to be sold or required to be sold. NEE and FPL adopted this model prospectively. See Note 1 – Measurement of Credit Losses on Financial Instruments.

For FPL's special use funds, changes in fair value of debt and equity securities, including any estimated credit losses of debt securities, result in a corresponding adjustment to the related regulatory asset or liability accounts, consistent with regulatory treatment. For NEE's non-rate regulated operations, changes in fair value of debt securities result in a corresponding adjustment to 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. Changes in fair value of 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.

Unrealized gains (losses) recognized on equity securities held at December 31, 2021, 2020 and 2019 are as follows:

	NEE						FPL
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
	(millions)
Unrealized gains	$	981	$	627	$	780	$	652	$	444	$	510

Realized gains and losses and proceeds from the sale or maturity of available for sale debt securities are as follows:

	NEE						FPL
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
	(millions)
Realized gains	$	78	$	110	$	68	$	59	$	83	$	44
Realized losses	$	73	$	70	$	48	$	57	$	56	$	29
Proceeds from sale or maturity of securities	$	1,831	$	2,541	$	3,005	$	1,330	$	2,162	$	2,539

The unrealized gains and unrealized losses on available for sale debt securities and the fair value of available for sale debt securities in an unrealized loss position are as follows:

	NEE				FPL
	December 31,				December 31,
	2021		2020		2021		2020
			(millions)
Unrealized gains	$	76	$	134	$	63	$	104
Unrealized losses(a)	$	19	$	9	$	15	$	9
Fair value	$	1,100	$	201	$	857	$	150

______________________

(a)Unrealized losses on available for sale debt securities in an unrealized loss position for greater than twelve months at December 31, 2021 and 2020 were not material to NEE or FPL.

Regulations issued by the FERC and the NRC provide general risk management guidelines to protect nuclear decommissioning funds and to allow such funds to earn a reasonable return. The FERC regulations prohibit, among other investments, investments in any securities of NEE or its subsidiaries, affiliates or associates, excluding investments tied to market indices or mutual funds. Similar restrictions applicable to the decommissioning funds for NEER's nuclear plants are included in the NRC operating licenses for those facilities or in NRC regulations applicable to NRC licensees not in cost-of-service environments. With respect to the decommissioning fund for Seabrook, decommissioning fund contributions and withdrawals are also regulated by the NDFC pursuant to New Hampshire law.

The nuclear decommissioning reserve funds are managed by investment managers who must comply with the guidelines of NEE and FPL and the rules of the applicable regulatory authorities. The funds' assets are invested giving consideration to taxes, liquidity, risk, diversification and other prudent investment objectives.

Nonrecurring Fair Value Measurements – NEE tests its equity method investments for impairment whenever events or changes in circumstances indicate that the investment may be impaired. During the preparation of NEE's December 31, 2020 financial statements, it was determined that NextEra Energy Resources' investment in Mountain Valley Pipeline, LLC (Mountain Valley Pipeline) accounted for under the equity method of accounting was other-than-temporarily impaired. The impairment is the result of continued legal and regulatory challenges that have resulted in substantial delays in achieving commercial operation and increased costs to complete construction. More specifically at the end of 2020 and into early 2021, developments in the legal, regulatory and political environment caused NextEra Energy Resources to consider the investment impaired and the impairment to be other than temporary. The challenges included legal challenges to the various permits needed to complete construction and the regulatory approvals received, regulatory challenges related to alternative construction plans and the extended construction period, and the political and environmental challenges with the construction of an interstate pipeline. Accordingly, NextEra Energy Resources performed a fair value analysis based on the market approach to determine the amount of the impairment. The challenges to complete construction and the resulting economic outlook for the pipeline were considered in determining the magnitude of the other-than-temporary impairment. Based on the fair value analysis, the equity method investment with a carrying amount of approximately $1.9 billion was written down to its estimated fair value of approximately $400 million as of December 31, 2020, resulting in an impairment charge of $1.5 billion (or $1.2 billion after tax), which is recorded in equity in

earnings (losses) of equity method investees in NEE’s consolidated statements of income for the year ended December 31, 2020.

The fair value estimate was based on a probability-weighted earnings before interest, taxes, depreciation and amortization (EBITDA) multiple valuation technique using a market participant view of the potential different outcomes for the investment. As part of the valuation, NextEra Energy Resources used observable inputs where available, including the EBITDA multiples of recent pipeline transactions. Significant unobservable inputs (Level 3), including the probabilities assigned to the different potential outcomes, the forecasts of operating revenues and costs, and the projected capital expenditures to complete the project, were also used in the estimation of fair value. An increase in the revenue forecasts, a decrease in the projected operating or capital expenditures or an increase in the probability assigned to the full pipeline being completed would result in an increased fair market value. Changes in the opposite direction of those unobservable inputs would result in a decreased fair market value.

On February 2, 2022, the U.S. Court of Appeals for the Fourth Circuit (the 4th Circuit) vacated and remanded Mountain Valley Pipeline’s Biological Opinion issued by the U.S. Fish and Wildlife Service. While NextEra Energy Resources continues to evaluate options and next steps with its joint venture partners, this event along with the 4th Circuit vacatur and remand of the U.S. Forest Service right-of-way grant on January 25, 2022 caused NextEra Energy Resources to re-evaluate its investment in Mountain Valley Pipeline for further other-than-temporary impairment, which evaluation coincided with the preparation of NEE's December 31, 2021 financial statements. As a result of this evaluation, it was determined that the continued legal and regulatory challenges have resulted in a very low probability of pipeline completion. Accordingly, NextEra Energy Resources updated its fair value estimate using the same probability-weighted EBITDA multiple valuation technique using a market participant view of the potential different outcomes for the investment as discussed above. Based on this fair value analysis, NextEra Energy Resources recorded an impairment charge in the first quarter of 2022 of approximately $0.8 billion ($0.6 billion after tax). This impairment charge resulted in the complete write off of NextEra Energy Resources’ equity method investment carrying amount of approximately $0.6 billion, as well as the recording of a liability of approximately $0.2 billion which reflects NextEra Energy Resources’ share of estimated future ARO costs.

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Income Taxes

12 Months Ended

Dec. 31, 2021

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

The components of income taxes are as follows:

	NEE						FPL
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
	(millions)
Federal:
Current	$	(26)	$	105	$	167	$	85	$	16	$	390
Deferred	311		(148)		115		545		474		(41)
Total federal	285		(43)		282		630		490		349
State:
Current	(62)		18		23		1		32		50
Deferred	125		69		143		207		156		85
Total state	63		87		166		208		188		135
Total income taxes	$	348	$	44	$	448	$	838	$	678	$	484

A reconciliation between the effective income tax rates and the applicable statutory rate is as follows:

	NEE						FPL
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%
Increases (reductions) resulting from:
State income taxes – net of federal income tax benefit(a)	1.6		2.8		3.4		4.1		4.2		3.5
Taxes attributable to noncontrolling interests	5.0		4.8		2.1		—		—		—
PTCs and ITCs – NEER	(10.3)		(11.8)		(7.2)		—		—		—
Amortization of deferred regulatory credit(b)	(4.4)		(7.2)		(6.2)		(3.5)		(4.9)		(8.0)
Foreign operations(c)	0.2		(2.4)		—		—		—		—
Other – net	(2.1)		(5.4)		(1.4)		(0.9)		(1.3)		(0.4)
Effective income tax rate	11.0	%	1.8	%	11.7	%	20.7	%	19.0	%	16.1	%

_________________________

(a)NEE's 2019 amount reflects a valuation allowance of approximately $48 million related to deferred state tax credits.

(b)2019 reflects an adjustment of approximately $83 million recorded by FPL to reduce income tax expense for the cumulative amortization of excess deferred income taxes from January 1, 2018 as a result of the FPSC's order in connection with its review of impacts associated with the Tax Cuts and Jobs Act. One of the provisions of the order requires FPL to amortize approximately $870 million of its excess deferred income taxes over a period not to exceed ten years.

(c)The 2020 gain on sale of the Spain solar projects was not taxable for federal and state income tax purposes (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests).

The income tax effects of temporary differences giving rise to consolidated deferred income tax liabilities and assets are as follows:

	NEE				FPL
	December 31,				December 31,
	2021		2020		2021		2020
	(millions)
Deferred tax liabilities:
Property-related	$	10,018	$	10,065	$	7,831	$	7,548
Pension	564		437		425		394
Investments in partnerships and joint ventures	2,783		2,238		3		3
Other	2,092		1,730		1,232		862
Total deferred tax liabilities	15,457		14,470		9,491		8,807
Deferred tax assets and valuation allowance:
Decommissioning reserves	296		290		296		290
Net operating loss carryforwards	330		299		2		3
Tax credit carryforwards	4,646		3,859		182		4
ARO and accrued asset removal costs	199		347		126		272
Regulatory liabilities	1,421		1,380		1,397		1,356
Other	733		755		351		363
Valuation allowance(a)	(282)		(289)		—		—
Net deferred tax assets	7,343		6,641		2,354		2,288
Net deferred income taxes	$	8,114	$	7,829	$	7,137	$	6,519

______________________

(a)Reflects valuation allowances related to deferred state tax credits and state operating loss carryforwards.

Deferred tax assets and liabilities are included on the consolidated balance sheets as follows:

	NEE				FPL
	December 31,				December 31,
	2021		2020		2021		2020
			(millions)
Noncurrent other assets	$	196	$	191	$	—	$	—
Deferred income taxes – noncurrent liabilities	(8,310)		(8,020)		(7,137)		(6,519)
Net deferred income taxes	$	(8,114)	$	(7,829)	$	(7,137)	$	(6,519)

The components of NEE's deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2021 are as follows:

	Amount			Expiration Dates
	(millions)
Net operating loss carryforwards:
Federal	$	51	(a)	2034 – 2038
State	264			2022 – 2041
Foreign	15			2022 – 2041
Net operating loss carryforwards	$	330
Tax credit carryforwards:
Federal	$	4,296		2030 – 2041
State	345		(b)	2022 – 2046
Foreign	5			2035 – 2041
Tax credit carryforwards	$	4,646

______________________

(a)Includes $49 million of net operating loss carryforwards with an indefinite expiration period.

(b)Includes $191 million of ITC carryforwards with an indefinite expiration period.

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Acquisitions Acquisitions

12 Months Ended

Dec. 31, 2021

Business Combinations [Abstract]

Acquisitions

Acquisitions

Gulf Power Company – On January 1, 2019, NEE acquired the outstanding common shares of Gulf Power Company, a rate-regulated electric utility under the jurisdiction of the FPSC, which served approximately 470,000 customers in eight counties throughout northwest Florida, had approximately 9,500 miles of transmission and distribution lines and owned approximately 2,300 MW of net generating capacity. The purchase price included approximately $4.44 billion in cash consideration and the assumption of approximately $1.3 billion of Gulf Power debt.

Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed on January 1, 2019 based on their fair value. The approval by the FPSC of Gulf Power's rates, which were intended to allow Gulf Power to collect from retail customers total revenues equal to Gulf Power's costs of providing service, including a reasonable rate of return on invested capital, was considered a fundamental input in measuring the fair value of Gulf Power's assets and liabilities and, as such, NEE concluded that the carrying values of all assets and liabilities recoverable through rates were representative of their fair values. As a result, NEE acquired assets of approximately $5.2 billion, primarily relating to property, plant and equipment of $4.0 billion and regulatory assets of $494 million, and assumed liabilities of approximately $3.4 billion, including $1.3 billion of long-term debt, $635 million of regulatory liabilities and $562 million of deferred income taxes. The excess of the purchase price over the fair value of assets acquired and liabilities assumed resulted in approximately $2.7 billion of goodwill which had been recognized on NEE's consolidated balance sheet. The goodwill arising from the transaction represents expected benefits from continued expansion of NEE's regulated businesses and the indefinite life of Gulf Power's service area franchise.

Merger of FPL and Gulf Power Company – 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 16. 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 Note 1 – Rate Regulation – Base Rates Effective January 2022 through December 2025. As a result of the merger, FPL acquired assets of approximately $6.7 billion, primarily relating to property, plant and equipment, net of approximately $4.9 billion and regulatory assets of $1.2 billion, and assumed liabilities of approximately $3.9 billion, including $1.8 billion of debt, primarily long-term debt, $729 million of deferred income taxes and $566 million of regulatory liabilities. Additionally, goodwill of approximately $2.7 billion and purchase accounting adjustments associated with the 2019 Gulf Power Company acquisition by NEE were transferred to FPL from Corporate and

Other at NEE. Goodwill associated with the Gulf Power Company acquisition is reflected within Corporate and Other at FPL and, for impairment testing, is included in the Gulf Power reporting unit. The assets acquired and liabilities assumed by FPL were at carrying amounts as the merger was between entities under common control.

Trans Bay Cable LLC – On July 16, 2019, a wholly owned subsidiary of NEET acquired the membership interests of Trans Bay Cable LLC (Trans Bay), which owns and operates a 53-mile, high-voltage direct current underwater transmission cable system in California extending from Pittsburg to San Francisco, with utility rates set by the FERC and revenues paid by the California Independent System Operator. The purchase price included approximately $670 million in cash consideration and the assumption of debt of approximately $422 million.

Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed based on their fair value. The approval by the FERC of Trans Bay’s rates, which is intended to allow Trans Bay to collect total revenues equal to Trans Bay's costs for the development, financing, construction, operation and maintenance of Trans Bay, including a reasonable rate of return on invested capital, is considered a fundamental input in measuring the fair value of Trans Bay's assets and liabilities and, as such, NEE concluded that the carrying values of all assets and liabilities recoverable through rates are representative of their fair values. As a result, NEE acquired assets of approximately $703 million, primarily relating to property, plant and equipment, and assumed liabilities of approximately $643 million, primarily relating to long-term debt. The excess of the purchase price over the fair value of assets acquired and liabilities assumed resulted in approximately $610 million of goodwill which has been recognized on NEE's consolidated balance sheet, of which approximately $572 million is expected to be deductible for tax purposes. Goodwill associated with the Trans Bay acquisition is reflected within NEER and, for impairment testing, is included in the rate-regulated transmission reporting unit. The goodwill arising from the transaction represents expected benefits from continued expansion of NEE's regulated businesses.

GridLiance – On March 31, 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 with approximately 700 miles of high-voltage transmission lines across six states, five in the Midwest and Nevada. The purchase price included approximately $502 million in cash consideration, and the assumption of approximately $175 million of debt, excluding post-closing adjustments.

Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed based on their fair value. The approval by the FERC of GridLiance's rates, which is intended to allow GridLiance to collect total revenues equal to GridLiance's costs for the development, financing, construction, operation and maintenance of GridLiance, including a reasonable rate of return on invested capital, is considered a fundamental input in measuring the fair value of GridLiance's assets and liabilities and, as such, NEE concluded that the carrying values of all assets and liabilities recoverable through rates are representative of their fair values. As a result, NEE acquired assets of approximately $384 million, primarily relating to property, plant and equipment, and assumed liabilities of approximately $210 million, primarily relating to long-term debt. The acquisition agreements are subject to earn-out provisions for additional payments, valued at approximately $264 million at March 31, 2021, to be made upon the completion of capital expenditures for future development projects (see Note 4 – Contingent Consideration). The excess of the purchase price over the fair value of assets acquired and liabilities assumed resulted in approximately $592 million of goodwill which has been recognized on NEE's consolidated balance sheet at December 31, 2021, of which approximately $586 million is expected to be deductible for tax purposes. Goodwill associated with the GridLiance acquisition is reflected within NEER and, for impairment testing, is included in the rate-regulated transmission reporting unit. The goodwill arising from the transaction represents expected benefits from continued expansion of NEE's regulated businesses. The valuation of the acquired net assets is subject to change as additional information related to the estimates is obtained during the measurement period.

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Property, Plant and Equipment

12 Months Ended

Dec. 31, 2021

Jointly-Owned Electric Plants [Abstract]

Property, Plant and Equipment

Property, Plant and Equipment

Property, plant and equipment consists of the following at December 31:

	NEE				FPL
	2021		2020		2021		2020
	(millions)
Electric plant in service and other property	$	112,500	$	105,860	$	67,771	$	62,963
Nuclear fuel	1,606		1,604		1,170		1,143
Construction work in progress	14,141		10,639		6,326		5,361
Property, plant and equipment, gross	128,247		118,103		75,267		69,467
Accumulated depreciation and amortization	(28,899)		(26,300)		(17,040)		(15,588)
Property, plant and equipment – net	$	99,348	$	91,803	$	58,227	$	53,879

FPL – At December 31, 2021, FPL's gross investment in electric plant in service and other property for the electric generation, transmission, distribution and general facilities of FPL represented approximately 46%, 13%, 35% and 6%, respectively; the

respective amounts at December 31, 2020 were 47%, 12%, 35% and 6%. Substantially all of FPL's properties are subject to the lien of FPL's mortgage, which secures most debt securities issued by FPL. The weighted annual composite depreciation and amortization rate for FPL's electric plant in service, including capitalized software, but excluding the effects of decommissioning, dismantlement and the depreciation adjustments discussed in the following sentence, was approximately 3.8%, 3.8% and 3.9% for 2021, 2020 and 2019, respectively. In accordance with the 2016 rate agreement (see Note 1 – Rate Regulation – Base Rates Effective January 2017 through December 2021), FPL recorded reserve amortization (reversal) of approximately $429 million, $(1) million and $(357) million in 2021, 2020 and 2019, respectively. During each of 2021, 2020 and 2019, the FPL segment capitalized AFUDC at a rate of 6.22%, which amounted to approximately $124 million, $79 million and $80 million, respectively. During each of 2021, 2020 and 2019, Gulf Power capitalized AFUDC at a rate of 5.73%, which amounted to approximately $53 million, $38 million and $6 million, respectively.

NEER – At December 31, 2021, wind, solar and nuclear plants represented approximately 53%, 14% and 8%, respectively, of NEER's depreciable electric plant in service and other property; the respective amounts at December 31, 2020 were 55%, 13% and 8%. The estimated useful lives of NEER's plants range primarily from 30 to 35 years for wind plants, 30 to 35 years for solar plants and 23 to 47 years for nuclear plants. NEER's oil and gas production assets represented approximately 14% and 14% of NEER's depreciable electric plant in service and other property at December 31, 2021 and 2020, respectively. A number of NEER's generation, regulated transmission and pipeline facilities are encumbered by liens securing various financings. The net book value of NEER's assets serving as collateral was approximately $13.5 billion at December 31, 2021. Interest capitalized on construction projects amounted to approximately $139 million, $168 million and $135 million during 2021, 2020 and 2019, respectively.

Jointly-Owned Electric Plants – Certain NEE subsidiaries own undivided interests in the jointly-owned facilities described below, and are entitled to a proportionate share of the output from those facilities. The subsidiaries are responsible for their share of the operating costs, as well as providing their own financing. Accordingly, each subsidiary's proportionate share of the facilities and related revenues and expenses is included in the appropriate balance sheet and statement of income captions. NEE's and FPL's respective shares of direct expenses for these facilities are included in fuel, purchased power and interchange expense, O&M expenses, depreciation and amortization expense and taxes other than income taxes and other – net in NEE's and FPL's consolidated statements of income.

NEE's and FPL's proportionate ownership interest in jointly-owned facilities is as follows:

	December 31, 2021
	Ownership Interest		Gross Investment(a)		Accumulated Depreciation(a)		Construction Work in Progress
			(millions)
FPL:
St. Lucie Unit No. 2	85	%	$	2,284	$	1,044	$	90
Daniel Units Nos. 1 and 2(b)	50	%	$	759	$	274	$	16
Scherer Unit No. 3(c)	25	%	$	449	$	204	$	3
NEER:
Seabrook	88.23	%	$	1,330	$	453	$	58
Wyman Station Unit No. 4	91.19	%	$	30	$	11	$	—
Stanton	65	%	$	139	$	19	$	—
Transmission substation assets located in Seabrook, New Hampshire	88.23	%	$	114	$	8	$	22

______________________

(a)Excludes nuclear fuel.

(b)FPL intends to retire its share of these units in 2024. Net book value is reflected in other property on NEE's and FPL's consolidated balance sheets.

(c)Together with its joint interest owner, FPL intends to retire this unit in 2028. Net book value is reflected in other property on NEE's and FPL's consolidated balance sheets.

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Equity Method Investments

12 Months Ended

Dec. 31, 2021

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments

Equity Method InvestmentsAt December 31, 2021 and 2020, NEE's equity method investments totaled approximately $6,159 million and $5,728 million, respectively. The principal entities included in investment in equity method investees on NEE's consolidated balance sheets are NEP OpCo, Sabal Trail Transmission, LLC (Sabal Trail) (see Note 15 – Contracts), Mountain Valley Pipeline (see Note 15 – Contracts), and Silver State South Solar, LLC. NEE's interest in these entities range from approximately 32% to 55%, and these entities own or are constructing natural gas pipelines or own electric generation facilities.

Summarized combined information for these principal entities is as follows:

	2021		2020
	(millions)
Operating revenue	$	1,469	$	1,359
Operating income	$	559	$	538
Net income	$	739	$	516
Total assets	$	29,537	$	22,717
Total liabilities	$	9,501	$	6,612
Partners'/members' equity(a)	$	20,036	$	16,105
NEE's share of underlying equity in the principal entities	$	4,352	$	3,927
Difference between investment carrying amount and underlying equity in net assets(b)	1,133		1,312
NEE's investment carrying amount for the principal entities	$	5,485	$	5,239

______________________

(a)Reflects NEE's interest, as well as third-party interests, in NEP OpCo.

(b)Approximately $2.6 billion in 2021 and $2.8 billion in 2020 is associated with NEP OpCo, of which approximately 75% and 70%, respectively, relates to goodwill and is not being amortized and the remaining balance is being amortized primarily over a period of 17 to 25 years. The difference for both years is net of an approximately $1.5 billion impairment charge in 2020 related to NextEra Energy Resources' investment in Mountain Valley Pipeline. In the first quarter of 2022, NextEra Energy Resources recorded an additional impairment charge to completely write off its investment in Mountain Valley Pipeline. See Note 4 – Nonrecurring Fair Value Measurements for a discussion of the impairment charges.

NextEra Energy Resources provides operational, management and administrative services as well as transportation and fuel management services to NEP and its subsidiaries under various agreements (service agreements). NextEra Energy Resources is also party to a cash sweep and credit support (CSCS) agreement with a subsidiary of NEP. At December 31, 2021 and 2020, the cash sweep amounts (due to NEP and its subsidiaries) held in accounts belonging to NextEra Energy Resources or its subsidiaries were approximately $57 million and $10 million, respectively, and are included in accounts payable. Fee income related to the CSCS agreement and the service agreements totaled approximately $148 million, $120 million and $101 million for the years ended December 31, 2021, 2020 and 2019, respectively, and is included in operating revenues in NEE's consolidated statements of income. Amounts due from NEP of approximately $113 million and $68 million are included in other receivables and $40 million and $32 million are included in noncurrent other assets at December 31, 2021 and 2020, respectively. See also Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests for amounts due to NEP for reimbursement of construction-related costs. NEECH or NextEra Energy Resources guaranteed or provided indemnifications, letters of credit or surety bonds totaling approximately $3,778 million at December 31, 2021 primarily related to obligations on behalf of NEP's subsidiaries with maturity dates ranging from 2022 to 2059, including certain project performance obligations, obligations under financing and interconnection agreements and obligations, primarily incurred and future construction payables, associated with the December 2021 sale of projects to NEP (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests). Payment guarantees and related contracts with respect to unconsolidated entities for which NEE or one of its subsidiaries are the guarantor are recorded on NEE’s consolidated balance sheets at fair value. At December 31, 2021, approximately $41 million related to the fair value of the credit support provided under the CSCS agreement is recorded as noncurrent other liabilities on NEE's consolidated balance sheet.

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Variable Interest Entities (VIEs)

12 Months Ended

Dec. 31, 2021

Variable Interest Entities [Abstract]

Variable Interest Entities (VIEs)

Variable Interest Entities (VIEs)

NEER – At December 31, 2021, NEE consolidates a number of VIEs within the NEER segment. Subsidiaries within the NEER segment are considered the primary beneficiary of these VIEs since they control the most significant activities of these VIEs, including operations and maintenance, and they have the obligation to absorb expected losses of these VIEs.

Eight indirect subsidiaries of NextEra Energy Resources have an ownership interest ranging from approximately 50% to 67% in entities which own and operate solar facilities with the capability of producing a total of approximately 772 MW. Each of the subsidiaries is considered a VIE since the non-managing members have no substantive rights over the managing members, and is consolidated by NextEra Energy Resources. These entities sell their electric output to third parties under power sales contracts with expiration dates ranging from 2035 through 2052. These entities have third-party debt which is secured by liens against the assets of the entities. The debt holders have no recourse to the general credit of NextEra Energy Resources for the repayment of debt. The assets and liabilities of these VIEs were approximately $1,851 million and $1,258 million, respectively, at December 31, 2021. There were three of these consolidated VIEs at December 31, 2020, and the assets and liabilities of those VIEs at such date totaled approximately $751 million and $607 million, respectively. At December 31, 2021 and 2020, the assets and liabilities of these VIEs consisted primarily of property, plant and equipment and long-term debt.

NEE consolidates a NEET VIE that is constructing an approximately 280-mile electricity transmission line. A NEET subsidiary is the primary beneficiary and controls the most significant activities during the construction period, including controlling the construction budget. NEET is entitled to receive 50% of the profits and losses of the entity. The assets and liabilities of the VIE totaled approximately $614 million and $64 million, respectively, at December 31, 2021, and $423 million and $68 million,

respectively, at December 31, 2020. At December 31, 2021 and 2020, the assets and liabilities of this VIE consisted primarily of property, plant and equipment and accounts payable.

NextEra Energy Resources consolidates a VIE which has a 10% direct ownership interest in wind generation facilities and solar facilities which have the capability of producing approximately 400 MW and 599 MW, respectively. These entities sell their electric output under power sales contracts to third parties with expiration dates ranging from 2025 through 2040. These entities are also considered a VIE because the holders of differential membership interests in these entities do not have substantive rights over the significant activities of these entities. The assets and liabilities of the VIE were approximately $1,518 million and $79 million, respectively, at December 31, 2021, and $1,572 million and $393 million, respectively, at December 31, 2020. At December 31, 2021 and 2020, the assets and liabilities of this VIE consisted primarily of property, plant and equipment and accounts payable.

The other 33 NextEra Energy Resources VIEs that are consolidated primarily relate to certain subsidiaries which have sold differential membership interests in entities which own and operate wind generation as well as solar and solar plus battery storage facilities with the capability of producing a total of approximately 10,626 MW and 890 MW, respectively, and own wind generation as well as solar and solar plus battery storage facilities that, upon completion of construction, which is anticipated in the first half of 2022, are expected to have a total capacity of approximately 200 MW and 625 MW, respectively. These entities sell, or will sell, their electric output either under power sales contracts to third parties with expiration dates ranging from 2024 through 2053 or in the spot market. These entities are considered VIEs because the holders of differential membership interests do not have substantive rights over the significant activities of these entities. NextEra Energy Resources has financing obligations with respect to these entities, including third-party debt which is secured by liens against the generation facilities and the other assets of these entities or by pledges of NextEra Energy Resources' ownership interest in these entities. The debt holders have no recourse to the general credit of NEER for the repayment of debt. The assets and liabilities of these VIEs totaled approximately $17,419 million and $1,480 million, respectively, at December 31, 2021, and $16,180 million and $1,741 million, respectively at December 31, 2020. At December 31, 2021 and 2020, the assets and liabilities of these VIEs consisted primarily of property, plant and equipment and accounts payable. At December 31, 2021, subsidiaries of NEE had guarantees related to certain obligations of two of these consolidated VIEs.

Other – At December 31, 2021 and 2020, several NEE subsidiaries had investments totaling approximately $4,559 million ($3,799 million at FPL) and $3,704 million ($3,124 million at FPL), respectively, which are included in special use funds and noncurrent other assets on NEE's consolidated balance sheets and in special use funds on FPL's consolidated balance sheets. These investments represented primarily commingled funds and mortgage-backed securities. NEE subsidiaries, including FPL, are not the primary beneficiaries and therefore do not consolidate any of these entities because they do not control any of the ongoing activities of these entities, were not involved in the initial design of these entities and do not have a controlling financial interest in these entities.

Certain subsidiaries of NEE have noncontrolling interests in entities accounted for under the equity method, including NEE's noncontrolling interest in NEP OpCo (see Note 8). These entities are limited partnerships or similar entity structures in which the limited partners or non-managing members do not have substantive rights over the significant activities of these entities, and therefore are considered VIEs. NEE is not the primary beneficiary because it does not have a controlling financial interest in these entities, and therefore does not consolidate any of these entities. NEE’s investment in these entities totaled approximately $4,214 million and $3,932 million at December 31, 2021 and 2020, respectively. At December 31, 2021, subsidiaries of NEE had guarantees related to certain obligations of one of these entities, as well as commitments to invest an additional approximately $110 million in several of these entities. See further discussion of such guarantees and commitments in Note 15 – Commitments and – Contracts, respectively.

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Leases

12 Months Ended

Dec. 31, 2021

Leases [Abstract]

Leases

LeasesNEE has operating and finance leases primarily related to purchased power agreements, land use agreements that convey exclusive use of the land during the arrangement for certain of its renewable energy projects and substations, buildings and equipment. Operating and finance leases primarily have fixed payments with expected expiration dates ranging from 2022 to 2083, with the exception of operating leases related to three land use agreements with an expiration date of 2106, some of which include options to extend the leases up to 20 years and some have options to terminate at NEE's discretion. At December 31, 2021, NEE’s ROU assets and lease liabilities for operating leases totaled approximately $547 million and $555 million, respectively; the respective amounts at December 31, 2020 were $535 million and $541 million. At December 31, 2021, NEE’s ROU assets and lease liabilities for finance leases totaled approximately $205 million and $200 million, respectively; the respective amounts at December 31, 2020 were $128 million and $124 million. NEE’s lease liabilities at December 31, 2021 and 2020 were calculated using a weighted-average incremental borrowing rate at the lease inception of 3.57% and 3.81%, respectively, for operating leases and 3.52% and 3.50%, respectively, for finance leases, and a weighted-average remaining lease term of 39 years and 33 years, respectively, for operating leases and 31 years and 25 years, respectively, for finance leases. At December 31, 2021, expected lease payments over the remaining terms of the leases were approximately $1.4 billion with no one year being material. NEE's operating lease cost for the years ended December 31, 2021, 2020 and 2019 totaled approximately $92 million, $95 million and $91 million, respectively. During the year ended December 31, 2021, 2020 and 2019,

NEE's ROU assets obtained in exchange for operating lease obligations totaled approximately $92 million, $121 million and $450 million, respectively, and in 2019 primarily relate to leases acquired with the Gulf Power ($262 million at FPL) and Trans Bay acquisitions (see Note 6). Other operating and finance lease-related amounts were not material to NEE's consolidated statements of income for the periods presented.

NEE has operating and sales-type leases primarily related to a natural gas and oil electric generation facility and certain battery storage facilities that sell their electric output under power sales agreements to third parties which provide the customers the ability to dispatch the facilities. At December 31, 2021 and 2020, NEE recorded a net investment in sales-type leases of approximately $42 million and $47 million, respectively. At December 31, 2021, the power sales agreements have expiration dates from 2024 to 2043 and NEE expects to receive approximately $843 million of lease payments over the remaining terms of the power sales agreements with no one year being material. Operating and sales-type lease-related amounts were not material to NEE's consolidated statements of income for the periods presented.

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Asset Retirement Obligations

12 Months Ended

Dec. 31, 2021

Asset Retirement Obligations [Abstract]

Asset Retirement Obligations

Asset Retirement Obligations

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. For NEE's rate-regulated operations, including FPL, the accounting provisions result in timing differences in the recognition of legal asset retirement costs for financial reporting purposes and the method the regulator allows for recovery in rates. See Note 1 – Rate Regulation and – Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs.

A rollforward of NEE's and FPL's AROs is as follows:

	NEE			FPL
	(millions)
Balances, December 31, 2019	$	3,506		$	2,410
Liabilities incurred	138			—
Accretion expense	169			103
Liabilities settled	(53)			(32)
Revision in estimated cash flows – net	(594)		(a)	(545)		(a)
Balances, December 31, 2020	3,166		(b)	1,936		(b)
Liabilities incurred	79			7
Accretion expense	141			78
Liabilities settled	(88)		(c)	(15)
Revision in estimated cash flows – net	(119)		(d)	101		(e)
Balances, December 31, 2021	$	3,179	(b)	$	2,107	(b)

______________________

(a)Primarily reflects the effect of revised cost estimates for decommissioning FPL's nuclear units consistent with the updated nuclear decommissioning studies filed with the FPSC in December 2020.

(b)Includes the current portion of AROs as of December 31, 2021 and 2020 of approximately $97 million ($58 million for FPL) and $109 million ($65 million for FPL), respectively, which are included in other current liabilities on NEE's and FPL's consolidated balance sheets.

(c)Includes approximately $35 million related to project sales to NEP as well as other sales of businesses and assets. See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

(d)The increase at FPL discussed in (e) was offset primarily by the effect of revised cost estimates and useful lives of NEER's solar facilities.

(e)Primarily reflects the effect of pending license extension requests of St. Lucie Units Nos. 1 and 2 for an additional 20 years.

Restricted funds for the payment of future expenditures to decommission NEE's and FPL's nuclear units included in special use funds on NEE's and FPL's consolidated balance sheets are presented below (see Note 4 – Special Use Funds). Duane Arnold is being actively decommissioned and was granted an exemption from the NRC, which allows for use of the funds for certain other site restoration activities in addition to decommissioning obligations recorded as AROs.

	NEE		FPL
	(millions)
Balances, December 31, 2021	$	8,846	$	6,082
Balances, December 31, 2020	$	7,703	$	5,271

NEE and FPL have identified but not recognized ARO liabilities related to the majority of their electric transmission and distribution assets and pipelines resulting from easements over property not owned by NEE or FPL. These easements are generally perpetual and only require retirement action upon abandonment or cessation of use of the property or facility for its specified purpose. The related ARO liability is not estimable for such easements as NEE and FPL intend to use these properties indefinitely. In the event NEE or FPL decide to abandon or cease the use of a particular easement, an ARO liability would be recorded at that time.

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Employee Retirement Benefits

12 Months Ended

Dec. 31, 2021

Retirement Benefits [Abstract]

Employee Retirement Benefits

Employee Retirement Benefits

Employee Pension Plan and Other Benefits Plans – NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries. NEE also has a supplemental executive retirement plan (SERP), which includes a non-qualified supplemental defined benefit pension component that provides benefits to a select group of management and highly compensated employees, and sponsors a contributory postretirement plan for other benefits for retirees of NEE and its subsidiaries meeting certain eligibility requirements. The total accrued benefit cost of the SERP and postretirement plans is approximately $300 million ($139 million for FPL) and $323 million ($156 million for FPL) at December 31, 2021 and 2020, respectively.

Pension Plan Assets, Benefit Obligations and Funded Status – The changes in assets, benefit obligations and the funded status of the pension plan are as follows:

	2021		2020
	(millions)
Change in pension plan assets:
Fair value of plan assets at January 1	$	5,314	$	4,800
Actual return on plan assets	627		723
Benefit payments	(253)		(209)
Fair value of plan assets at December 31	$	5,688	$	5,314
Change in pension benefit obligation:
Obligation at January 1	$	3,607	$	3,363
Service cost	90		85
Interest cost	64		92
Special termination benefit(a)	—		16
Plan amendments	—		1
Actuarial losses (gains) – net	(63)		259
Benefit payments	(253)		(209)
Obligation at December 31(b)	$	3,445	$	3,607
Funded status:
Prepaid pension benefit costs at NEE at December 31	$	2,243	$	1,707
Prepaid pension benefit costs at FPL at December 31(c)	$	1,657	$	1,550

_________________________

(a)Reflects enhanced early retirement benefit.

(b)NEE's accumulated pension benefit obligation, which includes no assumption about future salary levels, at December 31, 2021 and 2020 was approximately $3,352 million and $3,521 million, respectively.

(c)Reflects FPL's allocated benefits under NEE's pension plan.

NEE's unrecognized amounts included in accumulated other comprehensive income (loss) yet to be recognized as components of prepaid pension benefit costs are as follows:

	2021		2020
	(millions)
Unrecognized prior service benefit (net of $1 tax expense and $1 tax expense, respectively)	$	2	$	2
Unrecognized gains (losses) (net of $7 tax expense and $24 tax benefit, respectively)	41		(60)
Total	$	43	$	(58)

NEE's unrecognized amounts included in regulatory assets (liabilities) yet to be recognized as components of net prepaid pension benefit costs are as follows:

	2021		2020
	(millions)
Unrecognized prior service benefit	$	(1)	$	(1)
Unrecognized losses (gains)	(80)		163
Total	$	(81)	$	162

The following table provides the assumptions used to determine the benefit obligation for the pension plan. These rates are used in determining net periodic pension income in the following year.

	2021		2020
Discount rate(a)	2.87	%	2.53	%
Salary increase	4.90	%	4.40	%
Weighted-average interest crediting rate	3.79	%	3.82	%

_________________________

(a)The method of estimating the interest cost component of net periodic benefit costs uses a full yield curve approach by applying a specific spot rate along the yield curve.

NEE's investment policy for the pension plan recognizes the benefit of protecting the plan's funded status, thereby avoiding the necessity of future employer contributions. Its broad objectives are to achieve a high rate of total return with a prudent level of risk taking while maintaining sufficient liquidity and diversification to avoid large losses and preserve capital over the long term.

The NEE pension plan fund's current target asset allocation, which is expected to be reached over time, is 45% equity investments, 32% fixed income investments, 13% alternative investments and 10% convertible securities. The pension fund's investment strategy emphasizes traditional investments, broadly diversified across the global equity and fixed income markets, using a combination of different investment styles and vehicles. The pension fund's equity and fixed income holdings consist of both directly held securities as well as commingled investment arrangements such as common and collective trusts, pooled separate accounts, registered investment companies and limited partnerships. The pension fund's convertible security assets are principally direct holdings of convertible securities and include a convertible security oriented limited partnership. The pension fund's alternative investments consist primarily of private equity and real estate oriented investments in limited partnerships as well as absolute return oriented limited partnerships that use a broad range of investment strategies on a global basis.

The fair value measurements of NEE's pension plan assets by fair value hierarchy level are as follows:

	December 31, 2021(a)
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(millions)
Equity securities(b)	$	1,977	$	29	$	2	$	2,008
Equity commingled vehicles(c)	—		889		—		889
U.S. Government and municipal bonds	131		6		—		137
Corporate debt securities(d)	—		351		—		351
Asset-backed securities	—		386		—		386
Debt security commingled vehicles(e)	—		219		—		219
Convertible securities(f)	91		489		—		580
Total investments in the fair value hierarchy	$	2,199	$	2,369	$	2	4,570
Total investments measured at net asset value(g)							1,118
Total fair value of plan assets							$	5,688

_____________________

(a)See Notes 3 and 4 for discussion of fair value measurement techniques and inputs.

(b)Includes foreign investments of $927 million.

(c)Includes foreign investments of $169 million.

(d)Includes foreign investments of $109 million.

(e)Includes foreign investments of $5 million.

(f)Includes foreign investments of $41 million.

(g)Includes foreign investments of $220 million.

	December 31, 2020(a)
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(millions)
Equity securities(b)	$	2,017	$	10	$	3	$	2,030
Equity commingled vehicles(c)	—		668		—		668
U.S. Government and municipal bonds	169		8		—		177
Corporate debt securities(d)	—		340		—		340
Asset-backed securities	—		375		—		375
Debt security commingled vehicles(e)	—		201		—		201
Convertible securities(f)	64		453		—		517
Total investments in the fair value hierarchy	$	2,250	$	2,055	$	3	4,308
Total investments measured at net asset value(g)							1,006
Total fair value of plan assets							$	5,314

______________________

(a)See Notes 3 and 4 for discussion of fair value measurement techniques and inputs.

(b)Includes foreign investments of $881 million.

(c)Includes foreign investments of $156 million.

(d)Includes foreign investments of $93 million.

(e)Includes foreign investments of $5 million.

(f)Includes foreign investments of $35 million.

(g)Includes foreign investments of $153 million.

Expected Cash Flows – The following table provides information about benefit payments expected to be paid by the pension plan for each of the following calendar years (in millions):

2022	$	204
2023	$	208
2024	$	209
2025	$	210
2026	$	214
2027 – 2031	$	1,033

Net Periodic Income – The components of net periodic income for the plans are as follows:

	Pension Benefits						Postretirement Benefits
	2021		2020		2019		2021		2020		2019
			(millions)
Service cost	$	90	$	85	$	80	$	2	$	1	$	1
Interest cost	64		92		114		4		8		9
Expected return on plan assets	(339)		(321)		(312)		—		—		—
Amortization of actuarial loss	24		18		—		5		3		—
Amortization of prior service benefit	(1)		(1)		(1)		(15)		(16)		(15)
Special termination benefits	—		16		19		—		—		—
Net periodic income at NEE	$	(162)	$	(111)	$	(100)	$	(4)	$	(4)	$	(5)
Net periodic income allocated to FPL	$	(108)	$	(84)	$	(61)	$	(4)	$	(4)	$	(4)

Other Comprehensive Income – The components of net periodic income recognized in OCI for the pension plan are as follows:

	2021		2020		2019
	(millions)
Net gains (losses) (net of $29 tax expense, $13 tax expense and $10 tax benefit, respectively)	$	95	$	42	$	(36)
Amortization of unrecognized losses (net of $2 tax expense and $1 tax expense, respectively)	6		5		—
Total	$	101	$	47	$	(36)

Regulatory Assets (Liabilities) – The components of net periodic income recognized during the year in regulatory assets (liabilities) for the pension plan are as follows:

	2021		2020
	(millions)
Prior service cost (benefit)	$	(1)	$	1
Unrecognized gains	(226)		(89)
Amortization of prior service benefit	—		1
Amortization of unrecognized losses	(16)		(12)
Total	$	(243)	$	(99)

The assumptions used to determine net periodic pension income for the pension plan are as follows:

	2021		2020		2019
Discount rate	2.53	%	3.22	%	4.26	%
Salary increase	4.40	%	4.40	%	4.40	%
Expected long-term rate of return, net of investment management fees(a)	7.35	%	7.35	%	7.35	%
Weighted-average interest crediting rate	3.82	%	3.83	%	3.88	%

______________________

(a)In developing the expected long-term rate of return on assets assumption for its pension plan, NEE evaluated input, including other qualitative and quantitative factors, from its actuaries and consultants, as well as information available in the marketplace. 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. NEE also considered its pension fund's historical compounded returns.

Employee Contribution Plan – NEE offers an employee retirement savings plan which allows eligible participants to contribute a percentage of qualified compensation through payroll deductions. NEE makes matching contributions to participants' accounts. Defined contribution expense pursuant to this plan was approximately $66 million, $64 million and $58 million for NEE ($42 million, $40 million and $40 million for FPL) for the years ended December 31, 2021, 2020 and 2019, respectively.

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Debt

12 Months Ended

Dec. 31, 2021

Debt Disclosure [Abstract]

Debt

Debt

Long-term debt consists of the following:

	December 31,
	2021					2020
	Maturity Date	Balance		Weighted- Average Interest Rate		Balance			Weighted- Average Interest Rate
		(millions)				(millions)
FPL:
First mortgage bonds – fixed	2023 – 2051	$	14,290	4.20	%	$	13,090		4.32	%
Pollution control, solid waste disposal and industrial development revenue bonds – primarily variable(a)	2022 – 2050	1,407		0.15	%	1,407			0.17	%
Senior unsecured notes – primarily variable(b)(c)	2022 – 2071	2,697		1.37	%	2,621			1.55	%
Other long-term debt – variable(c)	2022 – 2046	307		0.82	%	300			0.70	%
Unamortized debt issuance costs and discount		(191)				(182)
Total long-term debt of FPL		18,510				17,236
Less current portion of long-term debt		536				354
Long-term debt of FPL, excluding current portion		17,974				16,882
NEER:
NextEra Energy Resources:
Senior secured limited-recourse long-term debt – variable(c)(d)	2024 – 2037	3,100		1.74	%	2,621			1.99	%
Senior secured limited-recourse long-term loans – fixed	2028 – 2049	2,475		3.30	%	704			3.59	%
Other long-term debt – primarily variable(c)(d)	2024 – 2048	785		2.50	%	450			2.72	%
NEET – long-term debt – primarily fixed(d)	2022 – 2049	1,151		2.69	%	937			3.09	%
Unamortized debt issuance costs and premium		(92)				(65)
Total long-term debt of NEER		7,419				4,647
Less current portion of long-term debt		664				239
Long-term debt of NEER, excluding current portion		6,755				4,408
NEECH:
Debentures – fixed	2023 – 2052	10,990		2.21	%	11,540		(d)	2.86	%
Debentures – variable(c)	2022 – 2023	3,850		0.56	%	1,225			0.80	%
Debentures, related to NEE's equity units – fixed	2024 – 2025	6,000		1.46	%	6,000			1.46	%
Junior subordinated debentures – primarily fixed(d)	2057 – 2082	3,723		4.54	%	3,693			4.78	%
Japanese yen denominated long-term debt – primarily variable(c)(d)(e)	2023 – 2030	582		1.49	%	650			1.49	%
Australian dollar denominated long-term debt – fixed(e)	2026	360		2.20	%	385			2.20	%
Other long-term debt – fixed	2022	186		0.92	%	221			0.92	%
Other long-term debt – variable(c)	2023 – 2024	1,245		0.64	%	600			0.70	%
Unamortized debt issuance costs, premium		(120)				(115)
Total long-term debt of NEECH		26,816				24,199
Less current portion of long-term debt		585				3,545
Long-term debt of NEECH, excluding current portion		26,231				20,654
Total long-term debt		$	50,960			$	41,944

______________________

(a)Includes variable rate tax exempt bonds that permit individual bondholders to tender the bonds for purchase at any time prior to maturity. In the event these variable rate tax exempt bonds are tendered for purchase, they would be remarketed by a designated remarketing agent in accordance with the related indenture. If the remarketing is unsuccessful, FPL would be required to purchase these variable rate tax exempt bonds. At December 31, 2021, these variable rate tax exempt bonds totaled approximately $1,375 million. All variable rate tax exempt bonds tendered for purchase have been successfully remarketed. FPL's syndicated revolving credit facilities are available to support the purchase of the variable rate tax exempt bonds. Variable interest rate is established at various intervals by the remarketing agent.

(b)At December 31, 2021, includes approximately $882 million of floating rate notes that permit individual noteholders to require repayment at specified dates prior to maturity. FPL’s syndicated revolving credit facilities are available to support the purchase of the floating rate notes.

(c)Variable rate is based on an underlying index plus a specified margin.

(d)Interest rate contracts, primarily swaps, have been entered into with respect to certain of these debt issuances. See Note 3.

(e)Foreign currency contracts have been entered into with respect to these debt issuances. See Note 3.

As of December 31, 2021, minimum annual maturities of long-term debt for NEE are approximately $1,785 million, $8,394 million, $3,672 million, $6,536 million and $1,322 million for 2022, 2023, 2024, 2025 and 2026, respectively. The respective amounts for FPL are approximately $536 million, $1,548 million, $646 million, $1,700 million and $0.2 million.

At December 31, 2021 and 2020, short-term borrowings had a weighted-average interest rate of 0.39% (0.27% for FPL) and 0.35% (0.28% for FPL), respectively. Subsidiaries of NEE, including FPL, had credit facilities with available capacity at December 31, 2021 of approximately $12.1 billion ($4.6 billion for FPL), of which approximately $11.1 billion ($4.6 billion for FPL)

relate to revolving line of credit facilities and $1.0 billion (none for FPL) relate to letter of credit facilities. Certain of the revolving line of credit facilities provide for the issuance of letters of credit which at December 31, 2021 had available capacity of approximately $1.9 billion ($647 million for FPL). The issuance of letters of credit under certain revolving line of credit facilities is subject to the aggregate commitment of the relevant banks to issue letters of credit under the applicable facility.

NEE has guaranteed certain payment obligations of NEECH, including most of those under NEECH's debt, including all of its debentures and commercial paper issuances, as well as most of its payment guarantees and indemnifications. NEECH has guaranteed certain debt and other obligations of subsidiaries within the NEER segment.

In August 2019, NEECH completed a remarketing of $1.5 billion aggregate principal amount of its Series I Debentures due September 1, 2021 (Series I Debentures) that were issued in August 2016 as components of equity units issued concurrently by NEE (August 2016 equity units). The Series I Debentures are fully and unconditionally guaranteed by NEE. In connection with the remarketing of the Series I Debentures, the interest rate on the Series I Debentures was reset to 2.403% per year, and interest is payable on March 1 and September 1 of each year, commencing September 1, 2019. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the August 2016 equity units, in the third quarter of 2019, NEE issued approximately 9.5 million shares of common stock (38.2 million shares after giving effect to the four-for-one stock split of NEE common stock effective October 26, 2020 (2020 stock split) in exchange for $1.5 billion.

As a result of the 2020 stock split (and adjustments related to the dividend rate), the fixed settlement rates of NEE’s three outstanding series of Corporate Units have been adjusted as described below. In addition, the Corporate Units provide that the applicable market value (as described below) for each series of Corporate Units will also be adjusted (when determined) to give effect to the 2020 stock split and certain other anti-dilution adjustments to determine the applicable settlement rate. However, for purposes of the presentation below, corresponding adjustments were instead made to the reference prices and the threshold appreciation prices for each series of Corporate Units to present the practical effect of the antidilution adjustments as of December 31, 2021.

In September 2019, NEE sold $1.5 billion of equity units (initially consisting of Corporate Units). Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series J Debenture due September 1, 2024, issued in the principal amount of $1,000 by NEECH. Each stock purchase contract requires the holder to purchase by no later than September 1, 2022 (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range described in the following sentence. If purchased on the final settlement date, as of December 31, 2021, the number of shares issued per equity unit would (subject to antidilution adjustments) range from 0.8973 shares if the applicable market value of a share of NEE common stock is less than or equal to $55.72 (the adjusted reference price) to 0.7181 shares if the applicable market value of a share is equal to or greater than $69.66 (the adjusted threshold appreciation price), with the applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending August 29, 2022. Total annual distributions on the equity units are at the rate of 4.872%, consisting of interest on the debentures (2.10% per year) and payments under the stock purchase contracts (2.772% per year). The interest rate on the debentures is expected to be reset on or after March 1, 2022. A holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit. The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder's obligation to purchase NEE common stock under the related stock purchase contract. If a successful remarketing does not occur on or before the third business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE.

In February 2020, NEE sold $2.5 billion of equity units (initially consisting of Corporate Units). Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series K Debenture due March 1, 2025, issued in the principal amount of $1,000 by NEECH. Each stock purchase contract requires the holder to purchase by no later than March 1, 2023 (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range described in the following sentence. If purchased on the final settlement date, as of December 31, 2021, the number of shares issued per equity unit would (subject to antidilution adjustments) range from 0.7104 shares if the applicable market value of a share of NEE common stock is less than or equal to $70.39 (the adjusted reference price) to 0.5681 shares if the applicable market value of a share is equal to or greater than $87.99 (the adjusted threshold appreciation price), with the applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending February 24, 2023. Total annual distributions on the equity units are at the rate of 5.279%, consisting of interest on the debentures (1.84% per year) and payments under the stock purchase contracts (3.439% per year). The interest rate on the debentures is expected to be reset on or after September 1, 2022. A holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit. The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder's obligation to purchase NEE common stock under the related stock purchase contract. If a successful remarketing does not occur on or before the third

business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE.

In September 2020, NEE sold $2.0 billion of equity units (initially consisting of Corporate Units). Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series L Debenture due September 1, 2025, issued in the principal amount of $1,000 by NEECH. Each stock purchase contract requires the holder to purchase by no later than September 1, 2023 (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range described in the following sentence. If purchased on the final settlement date, as of December 31, 2021, the number of shares issued per equity unit would (subject to antidilution adjustments) range from 0.6776 shares if the applicable market value of a share of NEE common stock is less than or equal to $73.79 (the adjusted reference price) to 0.5421 shares if the applicable market value of a share is equal to or greater than $92.24 (the adjusted threshold appreciation price), with the applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending August 29, 2023. Total annual distributions on the equity units are at the rate of 6.219%, consisting of interest on the debentures (0.509% per year) and payments under the stock purchase contracts (5.710% per year). The interest rate on the debentures is expected to be reset on or after March 1, 2023. A holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit. The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder's obligation to purchase NEE common stock under the related stock purchase contract. If a successful remarketing does not occur on or before the third business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE.

Prior to the issuance of NEE’s common stock, the stock purchase contracts, if dilutive, will be reflected in NEE’s diluted earnings per share calculations using the treasury stock method. Under this method, the number of shares of NEE common stock used in calculating diluted earnings per share is deemed to be increased by the excess, if any, of the number of shares that would be issued upon settlement of the stock purchase contracts over the number of shares that could be purchased by NEE in the market, at the average market price during the period, using the proceeds receivable upon settlement.

In January 2022, FPL sold $1.5 billion principal amount of its First Mortgage Bonds, 2.45% Series due February 3, 2032 and sold $1.0 billion principal amount of its Floating Rate Notes, Series due January 12, 2024.

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Equity

12 Months Ended

Dec. 31, 2021

Equity [Abstract]

Equity

Equity

Earnings Per Share – The reconciliation of NEE's basic and diluted earnings per share attributable to NEE is as follows:

	Years Ended December 31,
	2021		2020		2019
	(millions, except per share amounts)
Numerator – net income attributable to NEE	$	3,573	$	2,919	$	3,769
Denominator:
Weighted-average number of common shares outstanding – basic	1,962.5		1,959.0		1,927.9
Equity units, stock options, performance share awards and restricted stock(a)	9.7		9.8		14.0
Weighted-average number of common shares outstanding – assuming dilution	1,972.2		1,968.8		1,941.9
Earnings per share attributable to NEE:
Basic	$	1.82	$	1.49	$	1.95
Assuming dilution	$	1.81	$	1.48	$	1.94

______________________

(a)Calculated using the treasury stock method. Performance share awards are included in diluted weighted-average number of common shares outstanding based upon what would be issued if the end of the reporting period was the end of the term of the award.

Common shares issuable pursuant to equity units, stock options and/or performance share awards, as well as restricted stock which were not included in the denominator above due to their antidilutive effect were approximately 30.5 million, 27.1 million and 3.0 million for the years ended December 31, 2021, 2020 and 2019, respectively.

On September 14, 2020, NEE's board of directors approved a four-for-one split of NEE common stock effective October 26, 2020. NEE's authorized common stock increased from 800 million to 3.2 billion shares. All share and share-based data included in NEE's consolidated financial statements reflect the effect of the 2020 stock split.

Potentially Dilutive Securities at NEP – NEP senior unsecured convertible notes, when outstanding, are potentially dilutive securities to NEE. In June 2021 and December 2020, NEP issued $500 million and $600 million, respectively, principal amount of new senior unsecured convertible notes. Holders of these notes may convert all or a portion of the notes in accordance with the related indenture. Upon conversion, NEP will pay cash up to the principal amount of the notes to be converted and pay or deliver, as the case may be, cash, NEP common units or a combination of cash and common units, at NEP's election, in respect of the remainder, if any, of NEP's conversion obligation in excess of the principal amount of the notes being converted.

Common Stock Dividend Restrictions – NEE's charter does not limit the dividends that may be paid on its common stock. FPL's mortgage securing FPL's first mortgage bonds contains provisions which, under certain conditions, restrict the payment of dividends and other distributions to NEE. These restrictions do not currently limit FPL's ability to pay dividends to NEE.

Stock-Based Compensation – Net income for the years ended December 31, 2021, 2020 and 2019 includes approximately $119 million, $107 million and $100 million, respectively, of compensation costs and $19 million, $21 million and $17 million, respectively, of income tax benefits related to stock-based compensation arrangements. Compensation cost capitalized for the years ended December 31, 2021, 2020 and 2019 was not material. At December 31, 2021, there were approximately $148 million of unrecognized compensation costs related to nonvested/nonexercisable stock-based compensation arrangements. These costs are expected to be recognized over a weighted-average period of 2.8 years.

At December 31, 2021, approximately 84 million shares of common stock were authorized for awards to officers, employees and non-employee directors of NEE and its subsidiaries under NEE's: (a) 2021 Long Term Incentive Plan, (b) 2017 Non-Employee Directors Stock Plan and (c) earlier equity compensation plans under which shares are reserved for issuance under existing grants, but no additional shares are available for grant under the earlier plans. NEE satisfies restricted stock and performance share awards by issuing new shares of its common stock or by purchasing shares of its common stock in the open market. NEE satisfies stock option exercises by issuing new shares of its common stock. NEE generally grants most of its stock-based compensation awards in the first quarter of each year.

Restricted Stock and Performance Share Awards – Restricted stock typically vests within three years after the date of grant and is subject to, among other things, restrictions on transferability prior to vesting. The fair value of restricted stock is measured based upon the closing market price of NEE common stock as of the date of grant. Performance share awards are typically payable at the end of a three-year performance period if the specified performance criteria are met. The fair value for the majority of performance share awards is estimated based upon the closing market price of NEE common stock as of the date of grant less the present value of expected dividends, multiplied by an estimated performance multiple which is subsequently trued up based on actual performance. 

The activity in restricted stock and performance share awards for the year ended December 31, 2021 was as follows:

	Shares/Units	Weighted- Average Grant Date Fair Value Per Share/Units
Restricted Stock:
Nonvested balance, January 1, 2021	1,674,242	$	50.26
Granted	1,013,039	$	82.69
Vested	(835,919)	$	48.06
Forfeited	(33,630)	$	69.63
Nonvested balance, December 31, 2021	1,817,732	$	68.09
Performance Share Awards:
Nonvested balance, January 1, 2021	1,938,608	$	47.46
Granted	1,297,680	$	54.82
Vested	(1,738,904)	$	37.53
Forfeited	(85,235)	$	64.84
Nonvested balance, December 31, 2021	1,412,149	$	61.22

The weighted-average grant date fair value per share of restricted stock granted for the years ended December 31, 2020 and 2019 was $68.25 and $46.64 respectively. The weighted-average grant date fair value per share of performance share awards granted for the years ended December 31, 2020 and 2019 was $46.09 and $34.75, respectively.

The total fair value of restricted stock and performance share awards vested was $186 million, $177 million and $125 million for the years ended December 31, 2021, 2020 and 2019, respectively.

Options – Options typically vest within three years after the date of grant and have a maximum term of ten years. The exercise price of each option granted equals the closing market price of NEE common stock on the date of grant. The fair value of the options is estimated on the date of the grant using the Black-Scholes option-pricing model and based on the following assumptions:

	2021	2020	2019
Expected volatility(a)	17.32 – 17.75%	14.63 – 16.31%	14.20 – 14.31%
Expected dividends	2.30 – 2.44%	2.50 – 2.72%	2.85 – 2.93%
Expected term (years)(b)	7.0	7.0	7.0
Risk-free rate	0.80 – 1.27%	0.49 – 1.52%	2.24 – 2.54%

______________________

(a)Based on historical experience.

(b)Based on historical exercise and post-vesting cancellation experience adjusted for outstanding awards.

Option activity for the year ended December 31, 2021 was as follows:

	Shares Underlying Options	Weighted- Average Exercise Price Per Share		Weighted- Average Remaining Contractual Term (years)	Aggregate Intrinsic Value (millions)
Balance, January 1, 2021	9,618,204	$	38.32
Granted	1,220,265	$	83.33
Exercised	(738,516)	$	20.08
Forfeited	(86,641)	$	71.19
Balance, December 31, 2021	10,013,312	$	44.87	6.0	$	486
Exercisable, December 31, 2021	7,235,572	$	35.35	5.0	$	420

The weighted-average grant date fair value of options granted was $9.82, $7.08 and $5.01 per share for the years ended December 31, 2021, 2020 and 2019, respectively. The total intrinsic value of stock options exercised was approximately $49 million, $71 million and $81 million for the years ended December 31, 2021, 2020 and 2019, respectively.

Cash received from option exercises was approximately $15 million, $30 million and $34 million for the years ended December 31, 2021, 2020 and 2019, respectively. The tax benefits realized from options exercised were approximately $11 million, $17 million and $19 million for the years ended December 31, 2021, 2020 and 2019, respectively.

Preferred Stock – NEE's charter authorizes the issuance of 100 million shares of serial preferred stock, $0.01 par value, none of which are outstanding. FPL's charter authorizes the issuance of 10,414,100 shares of preferred stock, $100 par value, 5 million shares of subordinated preferred stock, no par value, and 5 million shares of preferred stock, no par value, none of which are outstanding.

Accumulated Other Comprehensive Income (Loss) – The components of AOCI, net of tax, are as follows:

	Accumulated Other Comprehensive Income (Loss)
	Net Unrealized Gains (Losses) on Cash Flow Hedges			Net Unrealized Gains (Losses) on Available for Sale Securities			Defined Benefit Pension and Other Benefits Plans			Net Unrealized Gains (Losses) on Foreign Currency Translation			Other Comprehensive Income (Loss) Related to Equity Method Investees		Total
	(millions)
Balances, December 31, 2018	$	(55)		$	(7)		$	(65)		$	(63)		$	2	$	(188)
Other comprehensive income (loss) before reclassifications	—			20			(46)			22			1		(3)
Amounts reclassified from AOCI	29		(a)	(2)		(b)	(3)		(c)	—			—		24
Net other comprehensive income (loss)	29			18			(49)			22			1		21
Less other comprehensive income attributable to noncontrolling interests	—			—			—			1			—		1
Acquisition of Gulf Power (see Note 6)	(1)			—			—			—			—		(1)
Balances, December 31, 2019	(27)			11			(114)			(42)			3		(169)
Other comprehensive income before reclassifications	—			12			37			13			1		63
Amounts reclassified from AOCI	12		(a)	(3)		(b)	2		(c)	—			—		11
Net other comprehensive income	12			9			39			13			1		74
Less other comprehensive income attributable to noncontrolling interests	—			—			—			7			—		7
Impact of disposal of a business	23		(d)	—			—			(13)		(d)	—		10
Balances, December 31, 2020	8			20			(75)			(49)			4		(92)
Other comprehensive income (loss) before reclassifications	—			(11)			95			(1)			1		84
Amounts reclassified from AOCI	6		(a)	(4)		(b)	5		(c)	—			—		7
Net other comprehensive income (loss)	6			(15)			100			(1)			1		91
Less other comprehensive loss attributable to noncontrolling interests	—			—			—			(1)			—		(1)
Balances, December 31, 2021	$	14		$	5		$	25		$	(49)		$	5	$	—
Attributable to noncontrolling interests	$	—		$	—		$	—		$	6		$	—	$	6

______________________

(a)Reclassified to interest expense in NEE's consolidated statements of income. See Note 3 – Income Statement Impact of Derivative Instruments.

(b)Reclassified to gains on disposal of investments and other property – net in NEE's consolidated statements of income.

(c)Reclassified to other net periodic benefit income in NEE's consolidated statements of income.

(d)Reclassified to gains on disposal of businesses/assets – net and interest expense in NEE's consolidated statements of income. See Note 3 – Income Statement Impact of Derivative Instruments and Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

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Commitments and Contingencies

12 Months Ended

Dec. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Commitments – NEE and its subsidiaries have made commitments in connection with a portion of their projected capital expenditures. Capital expenditures at FPL include, among other things, the cost for construction of additional facilities and equipment to meet customer demand, as well as capital improvements to and maintenance of existing facilities. At NEER, capital expenditures include, among other things, the cost, including capitalized interest, for construction and development of wind and solar projects, the procurement of nuclear fuel and the cost to maintain existing rate-regulated transmission facilities, as well as equity contributions to a joint venture for the development and construction of a rate-regulated transmission facility. Also see Note 4 – Contingent Consideration.

At December 31, 2021, estimated capital expenditures for 2022 through 2026 were as follows:

	2022		2023		2024		2025		2026		Total
	(millions)
FPL:
Generation:(a)
New(b)	$	1,825	$	1,670	$	1,635	$	1,210	$	995	$	7,335
Existing	1,605		1,465		1,220		685		750		5,725
Transmission and distribution(c)	4,035		3,760		3,870		4,760		5,075		21,500
Nuclear fuel	155		110		145		145		120		675
General and other	875		625		715		740		665		3,620
Total	$	8,495	$	7,630	$	7,585	$	7,540	$	7,605	$	38,855
NEER:(d)
Wind(e)	$	2,630	$	240	$	50	$	35	$	30	$	2,985
Solar(f)	3,445		1,010		170		25		10		4,660
Battery storage	270		120		—		—		5		395
Nuclear, including nuclear fuel	200		150		200		210		210		970
Rate-regulated transmission	220		85		55		30		30		420
Other	440		85		95		60		70		750
Total	$	7,205	$	1,690	$	570	$	360	$	355	$	10,180

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(a)Includes AFUDC of approximately $75 million, $85 million, $60 million, $50 million and $40 million for 2022 through 2026, respectively.

(b)Includes land, generation structures, transmission interconnection and integration and licensing.

(c)Includes AFUDC of approximately $50 million, $45 million, $40 million, $15 million and $0 million for 2022 through 2026, respectively.

(d)Represents capital expenditures for which applicable internal approvals and also, if required, regulatory approvals have been received.

(e)Consists of capital expenditures for new wind projects, repowering of existing wind projects and related transmission totaling approximately 2,852 MW.

(f)Includes capital expenditures for new solar projects (including solar plus battery storage projects) and related transmission totaling approximately 5,946 MW.

The above estimates are subject to continuing review and adjustment and actual capital expenditures may vary significantly from these estimates.

In addition to guarantees noted in Note 8 with regards to NEP, NEECH has guaranteed or provided indemnifications or letters of credit related to third parties, including certain obligations of investments in joint ventures accounted for under the equity method, totaling approximately $484 million at December 31, 2021. These obligations primarily related to guaranteeing the residual value of certain financing leases. Payment guarantees and related contracts with respect to unconsolidated entities for which NEE or one of its subsidiaries are the guarantor are recorded at fair value and are included in noncurrent other liabilities on NEE’s consolidated balance sheets. Management believes that the exposure associated with these guarantees is not material.

Contracts – In addition to the commitments made in connection with the estimated capital expenditures included in the table in Commitments above, FPL has firm commitments under long-term contracts primarily for the transportation of natural gas with expiration dates through 2042.

At December 31, 2021, NEER has entered into contracts with expiration dates through 2033 primarily for the purchase of wind turbines, wind towers and solar modules and related construction and development activities, as well as for the supply of uranium, and the conversion, enrichment and fabrication of nuclear fuel, and has made commitments for the construction of a rate-regulated transmission facility. Approximately $4.3 billion of related commitments are included in the estimated capital expenditures table in Commitments above. In addition, NEER has contracts primarily for the transportation and storage of natural gas with expiration dates through 2040.

The required capacity and/or minimum payments under contracts, including those discussed above at December 31, 2021, were estimated as follows:

	2022		2023		2024		2025		2026		Thereafter
	(millions)
FPL(a)	$	1,025	$	980	$	955	$	900	$	825	$	8,570
NEER(b)(c)(d)	$	4,400	$	365	$	185	$	85	$	65	$	570

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(a)Includes approximately $415 million, $410 million, $410 million, $405 million, $400 million and $5,960 million in 2022 through 2026 and thereafter, respectively, of firm commitments related to the natural gas transportation agreements with Sabal Trail and Florida Southeast Connection, LLC. The charges associated with these agreements are recoverable through the fuel clause and totaled approximately $419 million, $386 million and $316 million for the years ended December 31, 2021, 2020 and 2019, respectively, of which $105 million, $108 million and $108 million, respectively, were eliminated in consolidation at NEE.      

(b)Excludes commitments related to equity contributions and a 20-year natural gas transportation agreement (approximately $70 million per year) with a joint venture, in which NEER has a 31.9% equity investment, that is constructing a natural gas pipeline. These commitments are subject to the completion of construction of the pipeline which has a very low probability of completion. See Note 4 – Nonrecurring Fair Value Measurements.

(c)Includes approximately $370 million of commitments to invest in technology and other investments through 2031. See Note 9 – Other.

(d)Includes approximately $610 million, $20 million, $5 million, $5 million, $0 million and $5 million for 2022 through 2026 and thereafter, respectively, of joint obligations of NEECH and NEER.

Insurance – Liability for accidents at nuclear power plants is governed by the Price-Anderson Act, which limits the liability of nuclear reactor owners to the amount of insurance available from both private sources and an industry retrospective payment plan. In accordance with this Act, NEE maintains $450 million of private liability insurance per site, which is the maximum obtainable, except at Duane Arnold which obtained an exemption from the NRC and maintains a $100 million private liability insurance limit. Each site, except Duane Arnold, participates in a secondary financial protection system, which provides up to $13.1 billion of liability insurance coverage per incident at any nuclear reactor in the U.S. Under the secondary financial protection system, NEE is subject to retrospective assessments of up to $963 million ($550 million for FPL), plus any applicable taxes, per incident at any nuclear reactor in the U.S., payable at a rate not to exceed $143 million ($82 million for FPL) per incident per year. NextEra Energy Resources and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook and St. Lucie Unit No. 2, which approximates $16 million and $20 million, plus any applicable taxes, per incident, respectively.

NEE participates in a nuclear insurance mutual company that provides $2.75 billion of limited insurance coverage per occurrence per site for property damage, decontamination and premature decommissioning risks at its nuclear plants and a sublimit of $1.5 billion for non-nuclear perils, except for Duane Arnold which has a limit of $50 million for property damage, decontamination risks and non-nuclear perils. NEE participates in co-insurance of 10% of the first $400 million of losses per site per occurrence, except at Duane Arnold. The proceeds from such insurance, however, must first be used for reactor stabilization and site decontamination before they can be used for plant repair. NEE also participates in an insurance program that provides limited coverage for replacement power costs if a nuclear plant is out of service for an extended period of time because of an accident. In the event of an accident at one of NEE's or another participating insured's nuclear plants, NEE could be assessed up to $163 million ($104 million for FPL), plus any applicable taxes, in retrospective premiums in a policy year. NextEra Energy Resources and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook, Duane Arnold and St. Lucie Unit No. 2, which approximates $2 million, $2 million and $4 million, plus any applicable taxes, respectively.

Due to the high cost and limited coverage available from third-party insurers, NEE does not have property insurance coverage for a substantial portion of either its transmission and distribution property or natural gas pipeline assets. If FPL's future storm restoration costs exceed the storm and property insurance reserve, such storm restoration costs may be recovered, subject to prudence review by the FPSC, through surcharges approved by the FPSC or through securitization provisions pursuant to Florida law. See Note 1 – Storm Funds, Storm Reserves and Storm Cost Recovery.

In the event of a loss, the amount of insurance available might not be adequate to cover property damage and other expenses incurred. Uninsured losses and other expenses, to the extent not recovered from customers in the case of FPL, would be borne by NEE and FPL and could have a material adverse effect on NEE's and FPL's financial condition, results of operations and liquidity.

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Segment Information

12 Months Ended

Dec. 31, 2021

Segment Reporting [Abstract]

Segment Information

Segment InformationThe tables below present information for NEE's and FPL's reportable segments. NEE's segments include its reportable segments, the FPL segment, a rate-regulated utility business, and NEER, which is comprised of competitive energy and rate-regulated transmission businesses, as well as an operating segment of NEE, Gulf Power, a rate-regulated utility business. FPL's reportable segments include the FPL segment and Gulf Power. See Note 6 – Merger of FPL and Gulf Power Company. Corporate and Other for each of NEE and FPL represents other business activities, such as purchase accounting adjustments for Gulf Power Company, includes eliminating entries, and may include the net effect of rounding. See Note 2 for information regarding NEE's and FPL's operating revenues.

NEE's segment information is as follows:

	2021
	FPL Segment		Gulf Power		NEER(a)		Corp. and Other		NEE Consolidated
	(millions)
Operating revenues	$	12,600	$	1,503	$	3,053	$	(87)	$	17,069
Operating expenses – net	$	8,418	$	1,170	$	4,434	$	211	$	14,233
Gains (losses) on disposal of businesses/assets – net	$	1	$	—	$	78	$	(2)	$	77
Interest expense	$	588	$	28	$	367	$	287	$	1,270
Depreciation and amortization	$	1,968	$	297	$	1,576	$	83	$	3,924
Equity in earnings of equity method investees	$	—	$	—	$	666	$	—	$	666
Income tax expense (benefit)(b)	$	767	$	71	$	(395)	$	(95)	$	348
Net income (loss)	$	2,935	$	271	$	(147)	$	(232)	$	2,827
Net income (loss) attributable to NEE	$	2,935	$	271	$	599	$	(232)	$	3,573
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	6,785	$	782	$	8,363	$	147	$	16,077
Property, plant and equipment – net	$	52,728	$	5,499	$	40,900	$	221	$	99,348
Total assets	$	68,197	$	7,209	$	62,113	$	3,393	$	140,912
Investment in equity method investees	$	—	$	—	$	6,150	$	9	$	6,159

	2020
	FPL Segment		Gulf Power		NEER(a)		Corp. and Other		NEE Consolidated
	(millions)
Operating revenues	$	11,662	$	1,398	$	5,046	$	(109)	$	17,997
Operating expenses – net	$	7,862	$	1,081	$	4,125	$	166	$	13,234
Gains (losses) on disposal of businesses/assets – net	$	—	$	—	$	363	$	(10)	$	353
Interest expense	$	600	$	41	$	659	$	650	$	1,950
Depreciation and amortization	$	2,246	$	281	$	1,460	$	65	$	4,052
Equity in losses of equity method investees	$	—	$	—	$	(1,351)	$	—	$	(1,351)
Income tax expense (benefit)(b)	$	610	$	67	$	(416)	$	(217)	$	44
Net income (loss)	$	2,650	$	238	$	(19)	$	(500)	$	2,369
Net income (loss) attributable to NEE	$	2,650	$	238	$	531	$	(500)	$	2,919
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	6,680	$	1,012	$	6,893	$	25	$	14,610
Property, plant and equipment – net	$	48,933	$	4,946	$	37,842	$	82	$	91,803
Total assets	$	61,610	$	6,725	$	55,633	$	3,716	$	127,684
Investment in equity method investees	$	—	$	—	$	5,713	$	15	$	5,728

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(a)Interest expense allocated from NEECH is based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy Resources' subsidiaries. Residual NEECH corporate interest expense is included in Corporate and Other.

(b)NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 – Income Taxes.

	2019
	FPL Segment		Gulf Power		NEER(a)		Corp. and Other		NEE Consolidated
	(millions)
Operating revenues	$	12,192	$	1,487	$	5,639	$	(114)	$	19,204
Operating expenses – net	$	8,895	$	1,216	$	4,037	$	109	$	14,257
Gains (losses) on disposal of businesses/assets – net	$	5	$	—	$	402	$	(1)	$	406
Interest expense	$	594	$	55	$	873	$	727	$	2,249
Depreciation and amortization	$	2,524	$	247	$	1,387	$	58	$	4,216
Equity in earnings (losses) of equity method investees	$	—	$	—	$	67	$	(1)	$	66
Income tax expense (benefit)(b)	$	441	$	42	$	162	$	(197)	$	448
Net income (loss)	$	2,334	$	180	$	1,426	$	(552)	$	3,388
Net income (loss) attributable to NEE	$	2,334	$	180	$	1,807	$	(552)	$	3,769
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	5,755	$	729	$	6,505	$	4,473	$	17,462
Property, plant and equipment – net	$	45,074	$	4,763	$	32,042	$	131	$	82,010
Total assets	$	57,188	$	5,855	$	51,516	$	3,132	$	117,691
Investment in equity method investees	$	—	$	—	$	7,453	$	—	$	7,453

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(a)Interest expense allocated from NEECH is based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy Resources' subsidiaries. Residual NEECH corporate interest expense is included in Corporate and Other.

(b)NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 – Income Taxes.

FPL's segment information is as follows:

	2021								2020								2019
	FPL Segment		Gulf Power		Corp. and Other		FPL Consoli- dated		FPL Segment		Gulf Power		Corp. and Other		FPL Consoli-dated		FPL Segment		Gulf Power		Corp. and Other		FPL Consoli-dated
	(millions)
Operating revenues	$	12,600	$	1,503	$	(1)	$	14,102	$	11,662	$	1,398	$	—	$	13,060	$	12,192	$	1,487	$	1	$	13,680
Operating expenses – net (a)	$	8,418	$	1,170	$	(2)	$	9,586	$	7,862	$	1,081	$	(3)	$	8,940	$	8,895	$	1,216	$	(10)	$	10,101
Interest expense	$	588	$	28	$	(1)	$	615	$	600	$	41	$	—	$	641	$	594	$	55	$	—	$	649
Depreciation and amortization	$	1,968	$	297	$	1	$	2,266	$	2,246	$	281	$	(1)	$	2,526	$	2,524	$	247	$	—	$	2,771
Income tax expense	$	767	$	71	$	—	$	838	$	610	$	67	$	1	$	678	$	441	$	42	$	1	$	484
Net income	$	2,935	$	271	$	—	$	3,206	$	2,650	$	238	$	2	$	2,890	$	2,334	$	180	$	5	$	2,519
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	6,785	$	782	$	3	$	7,570	$	6,680	$	1,012	$	(13)	$	7,679	$	5,755	$	729	$	1	$	6,485
Property, plant and equipment – net	$	52,728	$	5,499	$	—	$	58,227	$	48,933	$	4,946	$	—	$	53,879	$	45,074	$	4,763	$	—	$	49,837
Total assets	$	68,197	$	7,209	$	2,661	$	78,067	$	61,610	$	6,725	$	2,666	$	71,001	$	57,188	$	5,855	$	2,647	$	65,690

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(a)FPL's income statement line for total operating expenses – net includes gains (losses) on disposal of businesses/assets – net.

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Summary of Significant Accounting and Reporting Policies (Policies)

12 Months Ended

Dec. 31, 2021

Accounting Policies [Abstract]

Basis of Presentation

Basis of Presentation – The operations of NextEra Energy, Inc. (NEE) are conducted primarily through Florida Power & Light Company (FPL), a wholly owned subsidiary, and NextEra Energy Resources, LLC (NextEra Energy Resources) and NextEra Energy Transmission, LLC (NEET) (collectively, NEER), wholly owned indirect subsidiaries that are combined for segment reporting purposes. 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 (FPL, excluding Gulf Power, related purchase accounting adjustments and eliminating entries) and the Gulf Power segment (Gulf Power) continued to be operating segments of NEE, as well as FPL, through 2021. 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 Rate Regulation – Base Rates Effective January 2022 through December 2025 below). The merger of FPL and Gulf Power Company was a merger between entities under common control, which required it to be accounted for as if the merger occurred since the inception of common control, with prior periods retrospectively adjusted to furnish comparative information. Accordingly, FPL's consolidated financial statements have been retrospectively adjusted to include the historical results and financial position of the common control merger prior to the merger date. See Note 6 – Merger of FPL and Gulf Power Company.

FPL's principal business is a rate-regulated electric utility which supplies electric service to more than 5.7 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 ownership interests in joint ventures. NEER participates in natural gas, natural gas liquids and oil production primarily through operating and non-operating ownership interests and in pipeline infrastructure through either wholly owned subsidiaries or noncontrolling or joint venture interests. NEER also invests in rate-regulated transmission facilities and transmission lines that connect its electric generation facilities to the electric grid through controlled and consolidated entities.

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 contingent 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 and 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 provide services to NEP under various related party operations and maintenance, administrative and management services agreements.

Operating Revenues

Operating Revenues – FPL and NEER generate substantially all of NEE’s operating revenues, which primarily include revenues from contracts with customers as further discussed in Note 2, as well as, at NEER, derivative and lease transactions. FPL's operating revenues include amounts resulting from base rates, cost recovery clauses (see Rate Regulation below), franchise fees, gross receipts taxes and surcharges related to storms (see Storm 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 $852 million, $800 million and $838 million in 2021, 2020 and 2019, 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

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,
	2021		2020		2021		2020
	(millions)
Regulatory assets:
Current:
Early retirement of generation facilities and transmission assets(a)	$	140	$	36	$	140	$	36
Acquisition of purchased power agreements(b)	141		161		141		161
Deferred clause and franchise expenses	698		28		698		28
Other	146		152		132		135
Total	$	1,125	$	377	$	1,111	$	360
Noncurrent:
Early retirement of generation facilities and transmission assets(a)	$	2,233	$	1,438	$	2,233	$	1,438
Acquisition of purchased power agreements(b)	332		473		332		473
Accrued asset removal costs(c)	263		—		263		—
Other	1,750		1,801		1,515		1,488
Total	$	4,578	$	3,712	$	4,343	$	3,399
Regulatory liabilities:
Current:
Deferred clause revenues	$	274	$	215	$	274	$	215
Other	15		30		4		9
Total	$	289	$	245	$	278	$	224
Noncurrent:
Asset retirement obligation regulatory expense difference	$	4,290	$	3,583	$	4,290	$	3,583
Accrued asset removal costs(c)	782		1,206		752		1,179
Deferred taxes	4,561		4,698		4,457		4,594
Other	1,640		1,248		1,554		1,244
Total	$	11,273	$	10,735	$	11,053	$	10,600

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(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)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, 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 underrecovery or overrecovery. Any underrecovered costs or overrecovered revenues are collected from or returned to customers in subsequent periods.

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.

Electric Plant, Depreciation and Amortization

Electric Plant, Depreciation and Amortization – The cost of additions to units of property of FPL and NEER is added to electric plant in service and other property. In accordance with regulatory accounting, the cost of FPL's units of utility property retired, less estimated net salvage value, is charged to accumulated depreciation. Maintenance and repairs of property as well as replacements and renewals of items determined to be less than units of utility property are charged to other operations and maintenance (O&M) expenses. 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, 2021 and 2020, convertible ITCs, net of amortization, were approximately $755 million ($116 million at FPL) and $791 million ($122 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. These new rates are expected to decrease depreciation expense. 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 noncurrent regulatory liabilities at December 31, 2020 on NEE's and FPL's consolidated balance sheets. The FPL segment used available reserve amortization to offset all of the storm restoration costs that were expensed during 2019 through 2021. See Storm Funds, Storm Reserves and Storm Cost Recovery below. 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

Nuclear Fuel – FPL and NEER have several contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel. See Note 15 – Contracts. FPL's and NEER's nuclear fuel costs are charged to fuel expense on a unit of production method.

Construction Activity

Construction Activity – Allowance for funds used during construction (AFUDC) is a noncash item which represents the allowed cost of capital, including an ROE, used to finance construction projects. FPL records the portion of AFUDC attributable to borrowed funds as a reduction of interest expense and the remainder as other income. FPSC rules limit the recording of AFUDC to projects that have an estimated cost in excess of 0.5% 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, 2021 and 2020, NEER's capitalized development costs totaled approximately $831 million and $571 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. In 2019, NEER determined it was no longer moving forward with the construction of a 220 MW wind facility due to unresolved permitting issues. NEE recorded charges of approximately $72 million ($54 million after tax), which are included in taxes other than income taxes and other – net in NEE’s consolidated statements of income for the year ended December 31, 2019, primarily related to the write-off of capitalized construction costs

Asset Retirement Obligations

Asset Retirement Obligations – NEE and FPL each account for asset retirement obligations and conditional asset retirement obligations (collectively, AROs) under accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated, with the offsetting associated asset retirement costs capitalized as part of the carrying amount of the long-lived assets. NEE's AROs relate primarily to decommissioning obligations of FPL's and NEER's nuclear units and to obligations for the dismantlement of certain of NEER's wind and solar facilities. See Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below and Note 11.

For NEE's rate-regulated operations, including FPL, the asset retirement cost is subsequently 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 subsequently allocated to expense using a systematic and rational method over the asset's estimated useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense, which is included in depreciation and amortization expense in NEE's consolidated statements of income. Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the asset retirement cost, or income when asset retirement cost is depleted.

Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs

Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs – For ratemaking purposes, FPL accrues for the cost of end of life retirement and disposal of its nuclear 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, and provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the dismantlement of St. Lucie Unit No. 2 in 2043. These studies also assume that FPL will be storing spent fuel on site pending removal to a United States (U.S.) government facility. 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 $10.2 billion, or $2.4 billion expressed in 2021 dollars. The ultimate costs of decommissioning reflect the application submitted to the U.S. Nuclear Regulatory Commission (NRC) for the extension of 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 2021, 2020 and 2019 fund earnings on decommissioning funds were approximately $173 million, $132 million and $125 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, 2021, FPL's portion of the ultimate cost to dismantle its other generation units is approximately $2.5 billion, or $1.2 billion expressed in 2021 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, 2021 and 2020, NEER's ARO was approximately $1.1 billion and $1.2 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 $9.4 billion, or $2.1 billion expressed in 2021 dollars. The ultimate cost to dismantle NEER's wind and solar facilities is estimated to be approximately $2.0 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

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 – Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less.

Restricted Cash

Restricted Cash – At December 31, 2021 and 2020, NEE had approximately $677 million ($53 million for FPL) and $441 million ($135 million for FPL), respectively, of restricted cash, of which approximately $677 million ($53 million for FPL) and $374 million ($93 million for FPL), respectively, are included in current other assets and the remaining balances are included in noncurrent 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 $121 million is netted against derivative assets and $172 million is netted against derivative liabilities at December 31, 2021 and $183 million is netted against derivative assets and $136 million is netted against derivative liabilities at December 31, 2020. See Note 3.

Measurement of Credit Losses on Financial Instruments

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. See also Note 4 – Special Use Funds.

Allowance for Doubtful Accounts

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, 2021, 2020 and 2019, NEE recorded approximately $146 million, $94 million and $32 million of bad debt expense, including credit losses, respectively, which are included in O&M expenses in NEE’s consolidated statements of income. The amount for the year ended December 31, 2021 primarily relates 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 are included in noncurrent other assets on NEE's consolidated balance sheet related to the February 2021 weather event.

Inventory

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

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

Storm Funds, Storm Reserves and Storm Cost Recovery – The storm and property insurance reserve funds (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 and property insurance reserves (storm reserves). 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 2021, 2020 and 2019, FPL’s service area was impacted by hurricanes and tropical storms, which resulted in the recording of incremental storm restoration costs. The FPL segment 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.

Restoration costs associated with multiple storms since 2018 that impacted FPL's customers in the former Gulf Power service area are being collected from northwest Florida customers through a storm damage surcharge through late 2024 and are recorded as regulatory assets. 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. As of December 31, 2020, the balance was $347 million, of which $100 million and $247 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

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

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, including FPL's, goodwill relates to various acquisitions which were accounted for using the purchase method of accounting. Other intangible assets are primarily included in noncurrent other assets on NEE's consolidated balance sheets. NEE's other intangible assets subject to amortization are amortized, primarily on a straight-line basis, over their estimated useful lives. Amortization expense was approximately $25 million, $27 million and $18 million for the years ended December 31, 2021, 2020 and 2019, respectively, and is expected to be approximately $16 million, $16 million, $18 million, $16 million and $16 million for 2022, 2023, 2024, 2025 and 2026, respectively.

Goodwill and other intangible assets not subject to amortization are assessed for impairment at least annually by applying a fair value-based analysis. Other intangible assets subject to amortization are periodically reviewed when impairment indicators are present to assess recoverability from future operations using undiscounted future cash flows.

Pension Plan

Pension Plan – NEE records the service cost component of net periodic benefit income to O&M expense and the non-service cost component to other net periodic benefit income in NEE's consolidated statements of income. NEE allocates net periodic pension income to its subsidiaries based on the pensionable earnings of the subsidiaries' employees. Accounting guidance requires recognition of the funded status of the pension plan in the balance sheet, with changes in the funded status recognized in other comprehensive income within shareholders' equity in the year in which the changes occur. Since NEE is the plan sponsor, and its subsidiaries do not have separate rights to the plan assets or direct obligations to their employees, this accounting guidance is reflected at NEE and not allocated to the subsidiaries. The portion of previously unrecognized actuarial gains and losses and prior service costs or credits that are estimated to be allocable to FPL as net periodic (income) cost in future periods and that otherwise would be recorded in accumulated other comprehensive income (AOCI) are classified as regulatory assets and liabilities at NEE in accordance with regulatory treatment.

Stock-Based Compensation

Stock-Based Compensation – NEE accounts for stock-based payment transactions based on grant-date fair value. Compensation costs for awards with graded vesting are recognized on a straight-line basis over the requisite service period for the entire award. Forfeitures of stock-based awards are recognized as they occur. See Note 14 – Stock-Based Compensation.

Retirement of Long-Term Debt

Retirement of Long-Term Debt – For NEE's rate-regulated subsidiaries, including FPL, gains and losses that result from differences in reacquisition cost and the net book value of long-term debt which is retired are deferred as a regulatory asset or liability and amortized to interest expense ratably over the remaining life of the original issue, which is consistent with their treatment in the ratemaking process. NEE's non-rate regulated subsidiaries recognize such differences in interest expense at the time of retirement.

Reference Rate Reform

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, 2022. 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, 2022 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.

Income Taxes

Income Taxes – Deferred income taxes are recognized on all significant temporary differences between the financial statement and tax bases of assets and liabilities, and are presented as noncurrent on NEE's and FPL's consolidated balance sheets. In connection with the tax sharing agreement between NEE and certain of its subsidiaries, the income tax provision at each applicable subsidiary reflects the use of the "separate return method," except that tax benefits that could not be used on a separate return basis, but are used on the consolidated tax return, are recorded by the applicable subsidiary that generated the tax benefits. Any remaining consolidated income tax benefits or expenses are recorded at the corporate level. Included in other regulatory assets and other regulatory liabilities on NEE's and FPL's consolidated balance sheets is the revenue equivalent of the difference in deferred income taxes computed under accounting rules, as compared to regulatory accounting rules. The net regulatory liability totaled $3,780 million ($3,723 million for FPL) and $3,949 million ($3,890 million for FPL) at December 31, 2021 and 2020, respectively, and is being amortized in accordance with the regulatory treatment over the estimated lives of the assets or liabilities for which the deferred tax amount was initially recognized.

Production tax credits (PTCs) are recognized as wind energy is generated and sold based on a per kWh rate prescribed in applicable federal and state statutes and are recorded as a reduction of current income taxes payable, unless limited by tax law in which instance they are recorded as deferred tax assets. NEER recognizes ITCs as a reduction to income tax expense when the related energy property is placed into service. FPL recognizes ITCs as a reduction to income tax expense over the depreciable life of the related energy property. At December 31, 2021 and 2020, FPL’s accumulated deferred ITCs were approximately $1,054 million and $753 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, 2021, NEE had unrecognized tax benefits of approximately $125 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.

Sale of Differential Membership Interests

Sales of Differential Membership Interests – Certain subsidiaries of NextEra Energy Resources sold Class B membership interests in entities that have ownership interests in wind and solar generation facilities, with generating capacity totaling approximately 11,226 MW and 1,894 MW, respectively, and battery storage capacity in operation or under construction totaling 220 MW at December 31, 2021, to third-party investors. NEE retains a controlling interest in the entities and therefore presents the Class B member interests as noncontrolling interests. Noncontrolling interests represents the portion of net assets in consolidated entities that are not owned by NEE and are reported as a component of equity in NEE’s consolidated balance sheet. The third-party investors are allocated earnings, tax attributes and cash flows in accordance with the respective limited liability company agreements. Those economics are allocated primarily to the third-party investors until they receive a targeted return (the flip date) and thereafter to NEE. NEE has the right to call the third-party interests at specified amounts if and when the flip date occurs. NEE has determined the allocation of economics between the controlling party and third-party investor should not follow the respective ownership percentages for each wind and solar project but rather the hypothetical liquidation of book value (HLBV) method based on the governing provisions in each respective limited liability company agreement. Under the HLBV method, the amounts of income and loss attributable to the noncontrolling interest reflects changes in the amount the owners would hypothetically receive at each balance sheet date under the respective liquidation provisions, assuming the net assets of these entities were liquidated at the recorded amounts, after taking into account any capital transactions, such as contributions and distributions, between the entities and the owners. At the point in time that the third-party investor, in hypothetical liquidation, would achieve its targeted return, NEE attributes the additional hypothetical proceeds to the Class B membership interests based on the call price. A loss attributable to noncontrolling interest on NEE’s consolidated statements of income represents earnings attributable to NEE.

Redeemable Noncontrolling Interests

Redeemable Noncontrolling Interests – Certain subsidiaries of NextEra Energy Resources sold Class B membership interests in entities that have ownership interests in wind 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 sheet as of December 31, 2021. These contingencies are expected to be resolved in 2022.

Variable Interest Entities (VIEs)

Variable Interest Entities (VIEs) – An entity is considered to be a VIE when its total equity investment at risk is not sufficient to permit the entity to finance its activities without additional subordinated financial support, or its equity investors, as a group, lack the characteristics of having a controlling financial interest. A reporting company is required to consolidate a VIE as its primary beneficiary when it has both the power to direct the activities of the VIE that most significantly impact the VIE's economic performance, and the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. NEE and FPL evaluate whether an entity is a VIE whenever reconsideration events as defined by the accounting guidance occur. See Note 9.

Leases

Leases – NEE and FPL determine if an arrangement is a lease at inception. NEE and FPL recognize a right-of-use (ROU) asset and a lease liability for operating and finance leases by recognizing and measuring leases at the commencement date based on the present value of lease payments over the lease term. For sales-type leases, the book value of the leased asset is removed from the balance sheet and a net investment in sales-type lease is recognized based on fixed payments under the contract and the residual value of the asset being leased. NEE and FPL have elected not to apply the recognition requirements to short-term leases and not to separate nonlease components from associated lease components for all classes of underlying assets except for purchased power agreements. ROU assets are included 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 a Business/Assets and Sale of Noncontrolling Ownership Interests

Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests – 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 are currently under construction with expected in-service dates in the first half of 2022. Total cash proceeds for these two separate transactions totaled approximately $1.7 billion, subject to working capital and other adjustments. NEER will continue to consolidate the three projects currently under construction for accounting purposes. 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) is reflected in the gains on disposal of businesses/assets – net in NEE’s consolidated statements of income for the year ended December 31, 2021. In connection with the three facilities currently 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. The contract liabilities relate 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 is contingent on the enactment of a solar PTC by a specified date in 2022. The contract liabilities associated with the sale proceeds and the differential membership interests are also subject to the three facilities under construction achieving commercial operations by specified dates in the first half of 2022. The contract liabilities will be reversed and the sale recognized for accounting purposes if the contingencies are resolved in 2022. Otherwise, NextEra Energy Resources may be required to return proceeds related to differential membership interests and/or repurchase the facilities for up to $668 million. In addition, NextEra Energy Resources is responsible to pay for all construction costs related to the portfolio. At December 31, 2021, approximately $970 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 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 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 December 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, in December 2020, 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) 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. In 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 at December 31, 2020. In connection with the solar-plus-storage facility transaction, approximately $155 million of cash received was recorded as a contract liability, which is included in current other liabilities on NEE's consolidated balance sheet at December 31, 2020. The solar-plus-storage facility achieved commercial operations in June 2021 and 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.

In 2019, subsidiaries of NextEra Energy Resources completed the sale of ownership interests in three wind generation facilities and three solar generation facilities, including noncontrolling interests in two of the solar facilities, located in the Midwest and West regions of the U.S. with a total net generating capacity of 611 MW to a NEP subsidiary for cash proceeds of approximately $1.0 billion, plus working capital of $12 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 $341 million ($259 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2019, which is included in gains on disposal of businesses/assets – net, and noncontrolling interests of approximately $118 million were recorded on NEE's consolidated balance sheet.

Revenue from Contracts with Customers

Revenue is recognized when control of the promised goods or services is transferred to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. The promised goods or services in the majority of NEE’s contracts with customers is, at FPL, for the delivery of electricity based on tariff rates approved by the FPSC and, at NEER, for the delivery of energy commodities and the availability of electric capacity and electric transmission.

FPL and NEER generate substantially all of NEE’s operating revenues, which primarily include revenues from contracts with customers, as well as derivative and lease transactions at NEER. For the vast majority of contracts with customers, NEE believes that the obligation to deliver energy, capacity or transmission is satisfied over time as the customer simultaneously receives and consumes benefits as NEE performs. In 2021, 2020 and 2019, NEE’s revenue from contracts with customers was approximately $18.8 billion ($14.1 billion at FPL), $17.0 billion ($13.0 billion at FPL) and $17.5 billion ($13.6 billion at FPL), respectively. NEE's and FPL's receivables are primarily associated with revenues earned from contracts with customers, as well as derivative and lease transactions at NEER, and consist of both billed and unbilled amounts, which are recorded in customer receivables and other receivables on NEE's and FPL's consolidated balance sheets. Receivables represent unconditional rights to consideration and reflect the differences in timing of revenue recognition and cash collections. For substantially all of NEE's and FPL's receivables, regardless of the type of revenue transaction from which the receivable originated, customer and counterparty credit risk is managed in the same manner and the terms and conditions of payment are similar. During 2021, NEER did not recognize approximately $180 million of revenue related to reimbursable expenses from a counterparty that are deemed not probable of collection. These reimbursable expenses arose from the impacts of the February 2021 weather event. These determinations were made based on assessments of the counterparty's creditworthiness and NEER's ability to collect.

FPL – FPL’s revenues are derived primarily from tariff-based sales that result from providing electricity to retail customers in Florida with no defined contractual term. Electricity sales to retail customers account for approximately 90% of FPL’s 2021 operating revenues, the majority of which are to residential customers. FPL’s retail customers receive a bill monthly based on the amount of monthly kWh usage with payment due monthly. For these types of sales, FPL recognizes revenue as electricity is delivered and billed to customers, as well as an estimate for electricity delivered and not yet billed. The billed and unbilled amounts represent the value of electricity delivered to the customer. At December 31, 2021 and 2020, FPL's unbilled revenues amounted to approximately $583 million and $454 million, respectively, and are included in customer receivables on NEE’s and FPL’s consolidated balance sheets. Certain contracts with customers contain a fixed price which primarily relate to certain power purchase agreements with maturity dates through 2041. As of December 31, 2021, FPL expects to record approximately $400 million of revenues related to the fixed capacity price components of such contracts over the remaining terms of the related

contracts as the capacity is provided. These contracts also contain a variable price component for energy usage which FPL recognizes as revenue as the energy is delivered based on rates stipulated in the respective contracts.

NEER – NEER’s revenue from contracts with customers is derived primarily from the sale of energy commodities, electric capacity and electric transmission. For these types of sales, NEER recognizes revenue as energy commodities are delivered and as electric capacity and electric transmission are made available, consistent with the amounts billed to customers based on rates stipulated in the respective contracts as well as an accrual for amounts earned but not yet billed. The amounts billed and accrued represent the value of energy or transmission delivered and/or the capacity of energy or transmission available to the customer. Revenues yet to be earned under these contracts, which have maturity dates ranging from 2022 to 2053, will vary based on the volume of energy or transmission delivered and/or available. NEER’s customers typically receive bills monthly with payment due within 30 days. Certain contracts with customers contain a fixed price which primarily relate to electric capacity sales associated with independent system operator annual auctions through 2025 and certain power purchase agreements with maturity dates through 2034. As of December 31, 2021, NEER expects to record approximately $735 million of revenues related to the fixed price components of such contracts over the remaining terms of the related contracts as the capacity is provided.

Derivatives

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, as well as interest rate and foreign currency exchange rate risk associated primarily with outstanding and expected future debt issuances and borrowings, and to optimize the value of NEER's power generation and gas infrastructure assets. NEE and FPL do not utilize hedge accounting for their cash flow and fair value hedges.

With respect to commodities related to NEE's competitive energy business, NEER employs risk management procedures to conduct its activities related to optimizing the value of its power generation and gas infrastructure assets, providing full energy and capacity requirements services primarily to distribution utilities, and engaging in power and fuel marketing and trading activities to take advantage of expected future favorable price movements and changes in the expected volatility of prices in the energy markets. These risk management activities involve the use of derivative instruments executed within prescribed limits to manage the risk associated with fluctuating commodity prices. Transactions in derivative instruments are executed on recognized exchanges or via the over-the-counter (OTC) markets, depending on the most favorable credit terms and market execution factors. For NEER's power generation and gas infrastructure assets, derivative instruments are used to hedge all or a portion of the expected output of these assets. These hedges are designed to reduce the effect of adverse changes in the wholesale forward commodity markets associated with NEER's power generation and gas infrastructure assets. With regard to full energy and capacity requirements services, NEER is required to vary the quantity of energy and related services based on the load demands of the customers served. For this type of transaction, derivative instruments are used to hedge the anticipated electricity quantities required to serve these customers and reduce the effect of unfavorable changes in the forward energy markets. Additionally, NEER takes positions in energy markets based on differences between actual forward market levels and management's view of fundamental market conditions, including supply/demand imbalances, changes in traditional flows of energy, changes in short- and long-term weather patterns and anticipated regulatory and legislative outcomes. NEER uses derivative instruments to realize value from these market dislocations, subject to strict risk management limits around market, operational and credit exposure.

Derivative instruments, when required to be marked to market, are recorded on NEE's and FPL's consolidated balance sheets as either an asset or liability measured at fair value. At FPL, substantially all changes in the derivatives' fair value are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the applicable fuel and purchased power cost recovery clause (fuel clause). For NEE's non-rate regulated operations, predominantly NEER, essentially all changes in the derivatives' fair value for power purchases and sales, fuel sales and trading activities are recognized on a net basis in operating revenues and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's consolidated statements of income. Settlement gains and losses are included within the line items in the consolidated statements of income to which they relate. Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the consolidated statements of income. For commodity derivatives, NEE believes that, where offsetting positions exist at the same location for the same time, the transactions are considered to have been netted and therefore physical delivery has been deemed not to have occurred for financial reporting purposes. Settlements related to derivative instruments are primarily recognized in net cash provided by operating activities in NEE's and FPL's consolidated statements of cash flows.

For interest rate and foreign currency derivative instruments, all changes in the derivatives' fair value, as well as the transaction gain or loss on foreign denominated debt, are recognized in interest expense and the equity method investees' related activity is recognized in equity in earnings (losses) of equity method investees in NEE's consolidated statements of income.

Fair Value of Financial Instruments

Fair Value Measurements of Derivative Instruments – The fair value of assets and liabilities are determined using either unadjusted quoted prices in active markets (Level 1) or pricing inputs that are observable (Level 2) whenever that information is available and using unobservable inputs (Level 3) to estimate fair value only when relevant observable inputs are not available. NEE and FPL use several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those assets and liabilities that are measured at fair value on a recurring basis. NEE's and FPL's assessment of the significance of any particular input to the fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Non-performance risk, including the consideration of a credit valuation adjustment, is also considered in the determination of fair value for all assets and liabilities measured at fair value.

NEE and FPL measure the fair value of commodity contracts using a combination of market and income approaches utilizing prices observed on commodities exchanges and in the OTC markets, or through the use of industry-standard valuation techniques, such as option modeling or discounted cash flows techniques, incorporating both observable and unobservable valuation inputs. The resulting measurements are the best estimate of fair value as represented by the transfer of the asset or liability through an orderly transaction in the marketplace at the measurement date.

Most exchange-traded derivative assets and liabilities are valued directly using unadjusted quoted prices. For exchange-traded derivative assets and liabilities where the principal market is deemed to be inactive based on average daily volumes and open interest, the measurement is established using settlement prices from the exchanges, and therefore considered to be valued using other observable inputs.

NEE, through its subsidiaries, including FPL, also enters into OTC commodity contract derivatives. The majority of these contracts are transacted at liquid trading points, and the prices for these contracts are verified using quoted prices in active markets from exchanges, brokers or pricing services for similar contracts.

NEE, through NEER, also enters into full requirements contracts, which, in most cases, meet the definition of derivatives and are measured at fair value. These contracts typically have one or more inputs that are not observable and are significant to the valuation of the contract. In addition, certain exchange and non-exchange traded derivative options at NEE have one or more significant inputs that are not observable, and are valued using industry-standard option models.

In all cases where NEE and FPL use significant unobservable inputs for the valuation of a commodity contract, consideration is given to the assumptions that market participants would use in valuing the asset or liability. The primary input to the valuation models for commodity contracts is the forward commodity curve for the respective instruments. Other inputs include, but are not limited to, assumptions about market liquidity, volatility, correlation and contract duration as more fully described below in Significant Unobservable Inputs Used in Recurring Fair Value Measurements. In instances where the reference markets are deemed to be inactive or do not have transactions for a similar contract, the derivative assets and liabilities may be valued using significant other observable inputs and potentially significant unobservable inputs. In such instances, the valuation for these contracts is established using techniques including extrapolation from or interpolation between actively traded contracts, or estimated basis adjustments from liquid trading points. NEE and FPL regularly evaluate and validate the inputs used to determine fair value by a number of methods, consisting of various market price verification procedures, including the use of pricing services and multiple broker quotes to support the market price of the various commodities. In all cases where there are assumptions and models used to generate inputs for valuing derivative assets and liabilities, the review and verification of the assumptions, models and changes to the models are undertaken by individuals that are independent of those responsible for estimating fair value.

NEE uses interest rate contracts and foreign currency contracts to mitigate and adjust interest rate and foreign currency exchange exposure related primarily to certain outstanding and expected future debt issuances and borrowings when deemed appropriate based on market conditions or when required by financing agreements. NEE estimates the fair value of these derivatives using an income approach based on a discounted cash flows valuation technique utilizing the net amount of estimated future cash inflows and outflows related to the agreements

Cash Equivalents and Restricted Cash Equivalents – NEE and FPL hold investments in money market funds. The fair value of these funds is estimated using a market approach based on current observable market prices.

Special Use Funds and Other Investments – NEE and FPL hold primarily debt and equity securities directly, as well as indirectly through commingled funds. Substantially all directly held equity securities are valued at their quoted market prices. For directly held debt securities, multiple prices and price types are obtained from pricing vendors whenever possible, which enables cross-provider validations. A primary price source is identified based on asset type, class or issue of each security. Commingled funds, which are similar to mutual funds, are maintained by banks or investment companies and hold certain investments in accordance with a stated set of objectives. The fair value of commingled funds is primarily derived from the quoted prices in active markets of the underlying securities. Because the fund shares are offered to a limited group of investors, they are not considered to be traded in an active market.

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Summary of Significant Accounting and Reporting Policies (Tables)

12 Months Ended

Dec. 31, 2021

Accounting Policies [Abstract]

Schedule of Regulatory Assets

NEE's and FPL's regulatory assets and liabilities are as follows:

	NEE				FPL
	December 31,				December 31,
	2021		2020		2021		2020
	(millions)
Regulatory assets:
Current:
Early retirement of generation facilities and transmission assets(a)	$	140	$	36	$	140	$	36
Acquisition of purchased power agreements(b)	141		161		141		161
Deferred clause and franchise expenses	698		28		698		28
Other	146		152		132		135
Total	$	1,125	$	377	$	1,111	$	360
Noncurrent:
Early retirement of generation facilities and transmission assets(a)	$	2,233	$	1,438	$	2,233	$	1,438
Acquisition of purchased power agreements(b)	332		473		332		473
Accrued asset removal costs(c)	263		—		263		—
Other	1,750		1,801		1,515		1,488
Total	$	4,578	$	3,712	$	4,343	$	3,399
Regulatory liabilities:
Current:
Deferred clause revenues	$	274	$	215	$	274	$	215
Other	15		30		4		9
Total	$	289	$	245	$	278	$	224
Noncurrent:
Asset retirement obligation regulatory expense difference	$	4,290	$	3,583	$	4,290	$	3,583
Accrued asset removal costs(c)	782		1,206		752		1,179
Deferred taxes	4,561		4,698		4,457		4,594
Other	1,640		1,248		1,554		1,244
Total	$	11,273	$	10,735	$	11,053	$	10,600

______________________

(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)See Electric Plant, Depreciation and Amortization below.

Schedule of Regulatory Liabilities

NEE's and FPL's regulatory assets and liabilities are as follows:

	NEE				FPL
	December 31,				December 31,
	2021		2020		2021		2020
	(millions)
Regulatory assets:
Current:
Early retirement of generation facilities and transmission assets(a)	$	140	$	36	$	140	$	36
Acquisition of purchased power agreements(b)	141		161		141		161
Deferred clause and franchise expenses	698		28		698		28
Other	146		152		132		135
Total	$	1,125	$	377	$	1,111	$	360
Noncurrent:
Early retirement of generation facilities and transmission assets(a)	$	2,233	$	1,438	$	2,233	$	1,438
Acquisition of purchased power agreements(b)	332		473		332		473
Accrued asset removal costs(c)	263		—		263		—
Other	1,750		1,801		1,515		1,488
Total	$	4,578	$	3,712	$	4,343	$	3,399
Regulatory liabilities:
Current:
Deferred clause revenues	$	274	$	215	$	274	$	215
Other	15		30		4		9
Total	$	289	$	245	$	278	$	224
Noncurrent:
Asset retirement obligation regulatory expense difference	$	4,290	$	3,583	$	4,290	$	3,583
Accrued asset removal costs(c)	782		1,206		752		1,179
Deferred taxes	4,561		4,698		4,457		4,594
Other	1,640		1,248		1,554		1,244
Total	$	11,273	$	10,735	$	11,053	$	10,600

______________________

(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)See Electric Plant, Depreciation and Amortization below.

Schedule of Goodwill and Other Intangible Assets

NEE's goodwill and other intangible assets are as follows:

	Weighted- Average Useful Lives	December 31,
		2021		2020
	(years)	(millions)
Goodwill (by reporting unit):
FPL segment:
Florida City Gas		$	292	$	292
Other		9		9
Gulf Power (see Note 6 – Merger of FPL and Gulf Power Company)		2,688		2,688
NEER segment:
Rate-regulated transmission (see Note 6 – GridLiance)		1,206		614
Gas infrastructure		487		487
Customer supply and trading		95		93
Generation assets		56		60
Corporate and Other		11		11
Total goodwill		$	4,844	$	4,254
Other intangible assets not subject to amortization, primarily land easements		$	136	$	135
Other intangible assets subject to amortization:
Purchased power agreements	15	$	507	$	453
Other, primarily transportation contracts and customer lists	23	187		166
Total		694		619
Accumulated amortization		(88)		(61)
Total other intangible assets subject to amortization – net		$	606	$	558

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Derivative Instruments (Tables)

12 Months Ended

Dec. 31, 2021

Derivative [Line Items]

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis

Therefore, the tables below also present the derivative positions on a net basis, which reflect the offsetting of positions of certain transactions within the portfolio, the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral, as well as the location of the net derivative position on the consolidated balance sheets.

	December 31, 2021
	Level 1		Level 2		Level 3		Netting(a)		Total
	(millions)
Assets:
NEE:
Commodity contracts	$	1,896	$	5,082	$	1,401	$	(6,622)	$	1,757
Interest rate contracts	$	—	$	106	$	—	$	(30)	76
Foreign currency contracts	$	—	$	8	$	—	$	(17)	(9)
Total derivative assets									$	1,824
FPL – commodity contracts	$	—	$	3	$	13	$	(3)	$	13
Liabilities:
NEE:
Commodity contracts	$	2,571	$	4,990	$	1,231	$	(6,594)	$	2,198
Interest rate contracts	$	—	$	739	$	—	$	(30)	709
Foreign currency contracts	$	—	$	86	$	—	$	(17)	69
Total derivative liabilities									$	2,976
FPL – commodity contracts	$	—	$	8	$	5	$	(3)	$	10
Net fair value by NEE balance sheet line item:
Current derivative assets(b)									$	689
Noncurrent derivative assets(c)									1,135
Total derivative assets									$	1,824
Current derivative liabilities(d)									$	1,263
Noncurrent derivative liabilities(e)									1,713
Total derivative liabilities									$	2,976
Net fair value by FPL balance sheet line item:
Current other assets									$	13
Current other liabilities									$	9
Noncurrent other liabilities									1
Total derivative liabilities									$	10

______________________

(a)Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the consolidated balance sheets and are recorded in customer receivables – net and accounts payable, respectively.

(b)Reflects the netting of approximately $150 million in margin cash collateral received from counterparties.

(c)Reflects the netting of approximately $56 million in margin cash collateral received from counterparties.

(d)Reflects the netting of approximately $6 million in margin cash collateral paid to counterparties.

(e)Reflects the netting of approximately $172 million in margin cash collateral paid to counterparties.

	December 31, 2020
	Level 1		Level 2		Level 3		Netting(a)		Total
	(millions)
Assets:
NEE:
Commodity contracts	$	919	$	1,881	$	1,679	$	(2,325)	$	2,154
Interest rate contracts	$	—	$	81	$	—	$	(41)	40
Foreign currency contracts	$	—	$	57	$	—	$	(34)	23
Total derivative assets									$	2,217
FPL – commodity contracts	$	—	$	1	$	2	$	—	$	3
Liabilities:
NEE:
Commodity contracts	$	1,004	$	1,468	$	305	$	(2,277)	$	500
Interest rate contracts	$	—	$	1,042	$	—	$	(41)	1,001
Foreign currency contracts	$	—	$	43	$	—	$	(34)	9
Total derivative liabilities									$	1,510
FPL – commodity contracts	$	—	$	—	$	3	$	—	$	3
Net fair value by NEE balance sheet line item:
Current derivative assets									$	570
Noncurrent derivative assets(b)									1,647
Total derivative assets									$	2,217
Current derivative liabilities(c)									$	311
Noncurrent derivative liabilities									1,199
Total derivative liabilities									$	1,510
Net fair value by FPL balance sheet line item:
Current other assets									$	3
Current other liabilities									$	2
Noncurrent other liabilities									1
Total derivative liabilities									$	3

______________________

(a)Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the consolidated balance sheets and are recorded in customer receivables – net and accounts payable, respectively.

(b)Reflects the netting of approximately $184 million in margin cash collateral received from counterparties.

(c)Reflects the netting of approximately $136 million in margin cash collateral paid to counterparties.

NEE's and FPL's financial assets and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows:

	December 31, 2021
	Level 1		Level 2			Level 3		Total
	(millions)
Assets:
Cash equivalents and restricted cash equivalents:(a)
NEE – equity securities	$	176	$	—		$	—	$	176
FPL – equity securities	$	58	$	—		$	—	$	58
Special use funds:(b)
NEE:
Equity securities	$	2,538	$	2,973	(c)	$	—	$	5,511
U.S. Government and municipal bonds	$	770	$	75		$	—	$	845
Corporate debt securities	$	7	$	955		$	—	$	962
Mortgage-backed securities	$	—	$	431		$	—	$	431
Other debt securities	$	2	$	265		$	—	$	267
FPL:
Equity securities	$	862	$	2,690	(c)	$	—	$	3,552
U.S. Government and municipal bonds	$	624	$	44		$	—	$	668
Corporate debt securities	$	6	$	720		$	—	$	726
Mortgage-backed securities	$	—	$	313		$	—	$	313
Other debt securities	$	2	$	225		$	—	$	227
Other investments:(d)
NEE:
Equity securities	$	70	$	2		$	—	$	72
Debt securities	$	111	$	162		$	12	$	285
FPL – equity securities	$	13	$	—		$	—	$	13

______________________

(a)Includes restricted cash equivalents of approximately $56 million ($53 million for FPL) in current other assets on the consolidated balance sheets.

(b)Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below.

(c)Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

(d)Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets.

	December 31, 2020
	Level 1		Level 2			Level 3		Total
	(millions)
Assets:
Cash equivalents and restricted cash equivalents:(a)
NEE – equity securities	$	742	$	—		$	—	$	742
FPL – equity securities	$	137	$	—		$	—	$	137
Special use funds:(b)
NEE:
Equity securities	$	2,237	$	2,489	(c)	$	—	$	4,726
U.S. Government and municipal bonds	$	590	$	127		$	—	$	717
Corporate debt securities	$	1	$	870		$	—	$	871
Mortgage-backed securities	$	—	$	422		$	—	$	422
Other debt securities	$	—	$	124		$	—	$	124
FPL:
Equity securities	$	752	$	2,260	(c)	$	—	$	3,012
U.S. Government and municipal bonds	$	449	$	87		$	—	$	536
Corporate debt securities	$	—	$	627		$	—	$	627
Mortgage-backed securities	$	—	$	335		$	—	$	335
Other debt securities	$	—	$	119		$	—	$	119
Other investments:(d)
NEE:
Equity securities	$	62	$	—		$	—	$	62
Debt securities	$	91	$	127		$	—	$	218
FPL - equity securities	$	12	$	—		$	—	$	12

______________________

(a)Includes restricted cash equivalents of approximately $111 million ($91 million for FPL) in current other assets and $42 million ($42 million for FPL) in noncurrent other assets on the consolidated balance sheets.

(b)Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below.

(c)Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

(d)Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets.

Fair Value Inputs, Assets, Quantitative Information

The significant unobservable inputs used in the valuation of NEE's commodity contracts categorized as Level 3 of the fair value hierarchy at December 31, 2021 are as follows:

Transaction Type	Fair Value at December 31, 2021				Valuation Technique(s)	Significant Unobservable Inputs	Range			Weighted-average(a)
	Assets		Liabilities
	(millions)
Forward contracts – power	$	433	$	204	Discounted cash flow	Forward price (per MWh(b))	$(5)	—	$140	$37
Forward contracts – gas	191		31		Discounted cash flow	Forward price (per MMBtu(c))	$2	—	$15	$3
Forward contracts – congestion	29		8		Discounted cash flow	Forward price (per MWh(b))	$(10)	—	$45	$—
Options – power	52		(1)		Option models	Implied correlations	32%	—	86%	52%
						Implied volatilities	8%	—	368%	81%
Options – primarily gas	356		347		Option models	Implied correlations	32%	—	86%	52%
						Implied volatilities	17%	—	295%	36%
Full requirements and unit contingent contracts	200		566		Discounted cash flow	Forward price (per MWh(b))	$2	—	$308	$64
						Customer migration rate(d)	—%	—	19%	2%
Forward contracts – other	140		76
Total	$	1,401	$	1,231

______________________

(a)Unobservable inputs were weighted by volume.

(b)Megawatt-hours

(c)One million British thermal units

(d)Applies only to full requirements contracts.

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation

The sensitivity of NEE's fair value measurements to increases (decreases) in the significant unobservable inputs is as follows:

Significant Unobservable Input	Position	Impact on Fair Value Measurement
Forward price	Purchase power/gas	Increase (decrease)
	Sell power/gas	Decrease (increase)
Implied correlations	Purchase option	Decrease (increase)
	Sell option	Increase (decrease)
Implied volatilities	Purchase option	Increase (decrease)
	Sell option	Decrease (increase)
Customer migration rate	Sell power(a)	Decrease (increase)

————————————

(a)Assumes the contract is in a gain position.

Reconciliation of changes in the fair value of derivatives measured based on significant unobservable inputs

The reconciliation of changes in the fair value of derivatives that are based on significant unobservable inputs is as follows:

	Years Ended December 31,
	2021				2020				2019
	NEE		FPL		NEE		FPL		NEE		FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year	$	1,374	$	(1)	$	1,207	$	(8)	$	647	$	(36)
Realized and unrealized gains (losses):
Included in earnings(a)	(1,488)		—		547		—		923		—
Included in other comprehensive income (loss)(b)	—		—		1		—		5		—
Included in regulatory assets and liabilities	8		8		2		2		1		1
Purchases	243		—		191		—		141		—
Sales(c)	—		—		114		—		—		—
Settlements	259		1		(562)		6		(356)		25
Issuances	(196)		—		(123)		—		(87)		—
Transfers in(d)	2		—		18		(1)		(5)		—
Transfers out(d)	(32)		—		(21)		—		(62)		2
Fair value of net derivatives based on significant unobservable inputs at December 31	$	170	$	8	$	1,374	$	(1)	$	1,207	$	(8)
Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date(e)	$	(924)	$	—	$	317	$	—	$	611	$	—

______________________

(a)For the years ended December 31, 2021, 2020 and 2019, realized and unrealized gains (losses) of approximately $(1,488) million, $569 million and $956 million are included in the consolidated statements of income in operating revenues and the balance is included in interest expense.

(b)Included in net unrealized gains (losses) on foreign currency translation in the consolidated statements of comprehensive income.

(c)See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

(d)Transfers into Level 3 were a result of decreased observability of market data. Transfers from Level 3 to Level 2 were a result of increased observability of market data.

(e)For the years ended December 31, 2021, 2020 and 2019, unrealized gains (losses) of approximately $(924) million, $317 million and $638 million are included in the consolidated statements of income in operating revenues and the balance is included in interest expense.

Derivative instruments, gain (loss) in statement of financial performance

Gains (losses) related to NEE's derivatives are recorded in NEE's consolidated statements of income as follows:

	Years Ended December 31,
	2021		2020		2019
	(millions)
Commodity contracts(a) – operating revenues	$	(2,710)	$	352	$	762
Foreign currency contracts – interest expense	(89)		8		(7)
Interest rate contracts – interest expense	264		(421)		(699)
Losses reclassified from AOCI:
Interest rate contracts(b)	(7)		(35)		(32)
Foreign currency contracts – interest expense	(3)		(3)		(4)
Total	$	(2,545)	$	(99)	$	20

______________________

(a)For the years ended December 31, 2021, 2020 and 2019, FPL recorded gains of approximately $7 million, $6 million and $9 million, respectively, related to commodity contracts as regulatory liabilities on its consolidated balance sheets.

(b)For the year ended December 31, 2020, approximately $23 million was reclassified to gains on disposal of businesses/assets – net (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests); remaining balances were reclassified to interest expense on NEE's consolidated statements of income.

Net notional volumes

NEE and FPL had derivative commodity contracts for the following net notional volumes:

	December 31, 2021				December 31, 2020
Commodity Type	NEE		FPL		NEE		FPL
	(millions)
Power	(103)	MWh	—		(90)	MWh	—
Natural gas	(1,290)	MMBtu	91	MMBtu	(607)	MMBtu	87	MMBtu
Oil	(33)	barrels	—		(6)	barrels	—

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Non-Derivative Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2021

Fair Value Disclosures [Abstract]

Financial assets and liabilities and other fair value measurements

Therefore, the tables below also present the derivative positions on a net basis, which reflect the offsetting of positions of certain transactions within the portfolio, the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral, as well as the location of the net derivative position on the consolidated balance sheets.

	December 31, 2021
	Level 1		Level 2		Level 3		Netting(a)		Total
	(millions)
Assets:
NEE:
Commodity contracts	$	1,896	$	5,082	$	1,401	$	(6,622)	$	1,757
Interest rate contracts	$	—	$	106	$	—	$	(30)	76
Foreign currency contracts	$	—	$	8	$	—	$	(17)	(9)
Total derivative assets									$	1,824
FPL – commodity contracts	$	—	$	3	$	13	$	(3)	$	13
Liabilities:
NEE:
Commodity contracts	$	2,571	$	4,990	$	1,231	$	(6,594)	$	2,198
Interest rate contracts	$	—	$	739	$	—	$	(30)	709
Foreign currency contracts	$	—	$	86	$	—	$	(17)	69
Total derivative liabilities									$	2,976
FPL – commodity contracts	$	—	$	8	$	5	$	(3)	$	10
Net fair value by NEE balance sheet line item:
Current derivative assets(b)									$	689
Noncurrent derivative assets(c)									1,135
Total derivative assets									$	1,824
Current derivative liabilities(d)									$	1,263
Noncurrent derivative liabilities(e)									1,713
Total derivative liabilities									$	2,976
Net fair value by FPL balance sheet line item:
Current other assets									$	13
Current other liabilities									$	9
Noncurrent other liabilities									1
Total derivative liabilities									$	10

______________________

(a)Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the consolidated balance sheets and are recorded in customer receivables – net and accounts payable, respectively.

(b)Reflects the netting of approximately $150 million in margin cash collateral received from counterparties.

(c)Reflects the netting of approximately $56 million in margin cash collateral received from counterparties.

(d)Reflects the netting of approximately $6 million in margin cash collateral paid to counterparties.

(e)Reflects the netting of approximately $172 million in margin cash collateral paid to counterparties.

	December 31, 2020
	Level 1		Level 2		Level 3		Netting(a)		Total
	(millions)
Assets:
NEE:
Commodity contracts	$	919	$	1,881	$	1,679	$	(2,325)	$	2,154
Interest rate contracts	$	—	$	81	$	—	$	(41)	40
Foreign currency contracts	$	—	$	57	$	—	$	(34)	23
Total derivative assets									$	2,217
FPL – commodity contracts	$	—	$	1	$	2	$	—	$	3
Liabilities:
NEE:
Commodity contracts	$	1,004	$	1,468	$	305	$	(2,277)	$	500
Interest rate contracts	$	—	$	1,042	$	—	$	(41)	1,001
Foreign currency contracts	$	—	$	43	$	—	$	(34)	9
Total derivative liabilities									$	1,510
FPL – commodity contracts	$	—	$	—	$	3	$	—	$	3
Net fair value by NEE balance sheet line item:
Current derivative assets									$	570
Noncurrent derivative assets(b)									1,647
Total derivative assets									$	2,217
Current derivative liabilities(c)									$	311
Noncurrent derivative liabilities									1,199
Total derivative liabilities									$	1,510
Net fair value by FPL balance sheet line item:
Current other assets									$	3
Current other liabilities									$	2
Noncurrent other liabilities									1
Total derivative liabilities									$	3

______________________

(a)Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the consolidated balance sheets and are recorded in customer receivables – net and accounts payable, respectively.

(b)Reflects the netting of approximately $184 million in margin cash collateral received from counterparties.

(c)Reflects the netting of approximately $136 million in margin cash collateral paid to counterparties.

NEE's and FPL's financial assets and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows:

	December 31, 2021
	Level 1		Level 2			Level 3		Total
	(millions)
Assets:
Cash equivalents and restricted cash equivalents:(a)
NEE – equity securities	$	176	$	—		$	—	$	176
FPL – equity securities	$	58	$	—		$	—	$	58
Special use funds:(b)
NEE:
Equity securities	$	2,538	$	2,973	(c)	$	—	$	5,511
U.S. Government and municipal bonds	$	770	$	75		$	—	$	845
Corporate debt securities	$	7	$	955		$	—	$	962
Mortgage-backed securities	$	—	$	431		$	—	$	431
Other debt securities	$	2	$	265		$	—	$	267
FPL:
Equity securities	$	862	$	2,690	(c)	$	—	$	3,552
U.S. Government and municipal bonds	$	624	$	44		$	—	$	668
Corporate debt securities	$	6	$	720		$	—	$	726
Mortgage-backed securities	$	—	$	313		$	—	$	313
Other debt securities	$	2	$	225		$	—	$	227
Other investments:(d)
NEE:
Equity securities	$	70	$	2		$	—	$	72
Debt securities	$	111	$	162		$	12	$	285
FPL – equity securities	$	13	$	—		$	—	$	13

______________________

(a)Includes restricted cash equivalents of approximately $56 million ($53 million for FPL) in current other assets on the consolidated balance sheets.

(b)Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below.

(c)Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

(d)Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets.

	December 31, 2020
	Level 1		Level 2			Level 3		Total
	(millions)
Assets:
Cash equivalents and restricted cash equivalents:(a)
NEE – equity securities	$	742	$	—		$	—	$	742
FPL – equity securities	$	137	$	—		$	—	$	137
Special use funds:(b)
NEE:
Equity securities	$	2,237	$	2,489	(c)	$	—	$	4,726
U.S. Government and municipal bonds	$	590	$	127		$	—	$	717
Corporate debt securities	$	1	$	870		$	—	$	871
Mortgage-backed securities	$	—	$	422		$	—	$	422
Other debt securities	$	—	$	124		$	—	$	124
FPL:
Equity securities	$	752	$	2,260	(c)	$	—	$	3,012
U.S. Government and municipal bonds	$	449	$	87		$	—	$	536
Corporate debt securities	$	—	$	627		$	—	$	627
Mortgage-backed securities	$	—	$	335		$	—	$	335
Other debt securities	$	—	$	119		$	—	$	119
Other investments:(d)
NEE:
Equity securities	$	62	$	—		$	—	$	62
Debt securities	$	91	$	127		$	—	$	218
FPL - equity securities	$	12	$	—		$	—	$	12

______________________

(a)Includes restricted cash equivalents of approximately $111 million ($91 million for FPL) in current other assets and $42 million ($42 million for FPL) in noncurrent other assets on the consolidated balance sheets.

(b)Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below.

(c)Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

(d)Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets.

Fair Value, by Balance Sheet Grouping

The carrying amounts of commercial paper and other short-term debt approximate their fair values. The carrying amounts and estimated fair values of other financial instruments recorded at other than fair value are as follows:

	December 31, 2021					December 31, 2020
	Carrying Amount		Estimated Fair Value			Carrying Amount		Estimated Fair Value
	(millions)
NEE:
Special use funds(a)	$	906	$	907		$	919	$	920
Other investments(b)	$	102	$	102		$	29	$	29
Long-term debt, including current portion	$	52,745	$	57,290	(c)	$	46,082	$	51,525	(c)
FPL:
Special use funds(a)	$	672	$	672		$	718	$	719
Long-term debt, including current portion	$	18,510	$	21,379	(c)	$	17,236	$	21,178	(c)

______________________

(a)Primarily represents investments accounted for under the equity method and loans not measured at fair value on a recurring basis (Level 2).

(b)Included in noncurrent other assets on NEE's consolidated balance sheets.

(c)At December 31, 2021 and 2020, substantially all is Level 2 for NEE and FPL.

Unrealized Gains (Losses) Recognized On Equity Securities

Unrealized gains (losses) recognized on equity securities held at December 31, 2021, 2020 and 2019 are as follows:

	NEE						FPL
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
	(millions)
Unrealized gains	$	981	$	627	$	780	$	652	$	444	$	510

Debt Securities, Available-for-sale

Realized gains and losses and proceeds from the sale or maturity of available for sale debt securities are as follows:

	NEE						FPL
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
	(millions)
Realized gains	$	78	$	110	$	68	$	59	$	83	$	44
Realized losses	$	73	$	70	$	48	$	57	$	56	$	29
Proceeds from sale or maturity of securities	$	1,831	$	2,541	$	3,005	$	1,330	$	2,162	$	2,539

The unrealized gains and unrealized losses on available for sale debt securities and the fair value of available for sale debt securities in an unrealized loss position are as follows:

	NEE				FPL
	December 31,				December 31,
	2021		2020		2021		2020
			(millions)
Unrealized gains	$	76	$	134	$	63	$	104
Unrealized losses(a)	$	19	$	9	$	15	$	9
Fair value	$	1,100	$	201	$	857	$	150

______________________

(a)Unrealized losses on available for sale debt securities in an unrealized loss position for greater than twelve months at December 31, 2021 and 2020 were not material to NEE or FPL.

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Income Taxes (Tables)

12 Months Ended

Dec. 31, 2021

Income Tax Disclosure [Abstract]

Components of income taxes

The components of income taxes are as follows:

	NEE						FPL
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
	(millions)
Federal:
Current	$	(26)	$	105	$	167	$	85	$	16	$	390
Deferred	311		(148)		115		545		474		(41)
Total federal	285		(43)		282		630		490		349
State:
Current	(62)		18		23		1		32		50
Deferred	125		69		143		207		156		85
Total state	63		87		166		208		188		135
Total income taxes	$	348	$	44	$	448	$	838	$	678	$	484

Reconciliation between the effective income tax rates and the applicable statutory rates

A reconciliation between the effective income tax rates and the applicable statutory rate is as follows:

	NEE						FPL
	Years Ended December 31,						Years Ended December 31,
	2021		2020		2019		2021		2020		2019
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%
Increases (reductions) resulting from:
State income taxes – net of federal income tax benefit(a)	1.6		2.8		3.4		4.1		4.2		3.5
Taxes attributable to noncontrolling interests	5.0		4.8		2.1		—		—		—
PTCs and ITCs – NEER	(10.3)		(11.8)		(7.2)		—		—		—
Amortization of deferred regulatory credit(b)	(4.4)		(7.2)		(6.2)		(3.5)		(4.9)		(8.0)
Foreign operations(c)	0.2		(2.4)		—		—		—		—
Other – net	(2.1)		(5.4)		(1.4)		(0.9)		(1.3)		(0.4)
Effective income tax rate	11.0	%	1.8	%	11.7	%	20.7	%	19.0	%	16.1	%

_________________________

(a)NEE's 2019 amount reflects a valuation allowance of approximately $48 million related to deferred state tax credits.

(b)2019 reflects an adjustment of approximately $83 million recorded by FPL to reduce income tax expense for the cumulative amortization of excess deferred income taxes from January 1, 2018 as a result of the FPSC's order in connection with its review of impacts associated with the Tax Cuts and Jobs Act. One of the provisions of the order requires FPL to amortize approximately $870 million of its excess deferred income taxes over a period not to exceed ten years.

(c)The 2020 gain on sale of the Spain solar projects was not taxable for federal and state income tax purposes (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests).

Schedule of deferred income tax liabilities and assets

The income tax effects of temporary differences giving rise to consolidated deferred income tax liabilities and assets are as follows:

	NEE				FPL
	December 31,				December 31,
	2021		2020		2021		2020
	(millions)
Deferred tax liabilities:
Property-related	$	10,018	$	10,065	$	7,831	$	7,548
Pension	564		437		425		394
Investments in partnerships and joint ventures	2,783		2,238		3		3
Other	2,092		1,730		1,232		862
Total deferred tax liabilities	15,457		14,470		9,491		8,807
Deferred tax assets and valuation allowance:
Decommissioning reserves	296		290		296		290
Net operating loss carryforwards	330		299		2		3
Tax credit carryforwards	4,646		3,859		182		4
ARO and accrued asset removal costs	199		347		126		272
Regulatory liabilities	1,421		1,380		1,397		1,356
Other	733		755		351		363
Valuation allowance(a)	(282)		(289)		—		—
Net deferred tax assets	7,343		6,641		2,354		2,288
Net deferred income taxes	$	8,114	$	7,829	$	7,137	$	6,519

______________________

(a)Reflects valuation allowances related to deferred state tax credits and state operating loss carryforwards.

Deferred tax assets and liabilities are included on the consolidated balance sheets as follows:

	NEE				FPL
	December 31,				December 31,
	2021		2020		2021		2020
			(millions)
Noncurrent other assets	$	196	$	191	$	—	$	—
Deferred income taxes – noncurrent liabilities	(8,310)		(8,020)		(7,137)		(6,519)
Net deferred income taxes	$	(8,114)	$	(7,829)	$	(7,137)	$	(6,519)

Components of deferred tax assets relating to net operating loss carryforwards

The components of NEE's deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2021 are as follows:

	Amount			Expiration Dates
	(millions)
Net operating loss carryforwards:
Federal	$	51	(a)	2034 – 2038
State	264			2022 – 2041
Foreign	15			2022 – 2041
Net operating loss carryforwards	$	330
Tax credit carryforwards:
Federal	$	4,296		2030 – 2041
State	345		(b)	2022 – 2046
Foreign	5			2035 – 2041
Tax credit carryforwards	$	4,646

______________________

(a)Includes $49 million of net operating loss carryforwards with an indefinite expiration period.

(b)Includes $191 million of ITC carryforwards with an indefinite expiration period.

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Property, Plant and Equipment (Tables)

12 Months Ended

Dec. 31, 2021

Jointly-Owned Electric Plants [Abstract]

Property, Plant and Equipment

Property, plant and equipment consists of the following at December 31:

	NEE				FPL
	2021		2020		2021		2020
	(millions)
Electric plant in service and other property	$	112,500	$	105,860	$	67,771	$	62,963
Nuclear fuel	1,606		1,604		1,170		1,143
Construction work in progress	14,141		10,639		6,326		5,361
Property, plant and equipment, gross	128,247		118,103		75,267		69,467
Accumulated depreciation and amortization	(28,899)		(26,300)		(17,040)		(15,588)
Property, plant and equipment – net	$	99,348	$	91,803	$	58,227	$	53,879

Proportionate Ownership Interest In Jointly-Owned Facilities

NEE's and FPL's proportionate ownership interest in jointly-owned facilities is as follows:

	December 31, 2021
	Ownership Interest		Gross Investment(a)		Accumulated Depreciation(a)		Construction Work in Progress
			(millions)
FPL:
St. Lucie Unit No. 2	85	%	$	2,284	$	1,044	$	90
Daniel Units Nos. 1 and 2(b)	50	%	$	759	$	274	$	16
Scherer Unit No. 3(c)	25	%	$	449	$	204	$	3
NEER:
Seabrook	88.23	%	$	1,330	$	453	$	58
Wyman Station Unit No. 4	91.19	%	$	30	$	11	$	—
Stanton	65	%	$	139	$	19	$	—
Transmission substation assets located in Seabrook, New Hampshire	88.23	%	$	114	$	8	$	22

______________________

(a)Excludes nuclear fuel.

(b)FPL intends to retire its share of these units in 2024. Net book value is reflected in other property on NEE's and FPL's consolidated balance sheets.

(c)Together with its joint interest owner, FPL intends to retire this unit in 2028. Net book value is reflected in other property on NEE's and FPL's consolidated balance sheets.

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Equity Method Investments (Tables)

12 Months Ended

Dec. 31, 2021

Equity Method Investments and Joint Ventures [Abstract]

Summarized combined information for principal operating entities

Summarized combined information for these principal entities is as follows:

	2021		2020
	(millions)
Operating revenue	$	1,469	$	1,359
Operating income	$	559	$	538
Net income	$	739	$	516
Total assets	$	29,537	$	22,717
Total liabilities	$	9,501	$	6,612
Partners'/members' equity(a)	$	20,036	$	16,105
NEE's share of underlying equity in the principal entities	$	4,352	$	3,927
Difference between investment carrying amount and underlying equity in net assets(b)	1,133		1,312
NEE's investment carrying amount for the principal entities	$	5,485	$	5,239

______________________

(a)Reflects NEE's interest, as well as third-party interests, in NEP OpCo.

(b)Approximately $2.6 billion in 2021 and $2.8 billion in 2020 is associated with NEP OpCo, of which approximately 75% and 70%, respectively, relates to goodwill and is not being amortized and the remaining balance is being amortized primarily over a period of 17 to 25 years. The difference for both years is net of an approximately $1.5 billion impairment charge in 2020 related to NextEra Energy Resources' investment in Mountain Valley Pipeline. In the first quarter of 2022, NextEra Energy Resources recorded an additional impairment charge to completely write off its investment in Mountain Valley Pipeline. See Note 4 – Nonrecurring Fair Value Measurements for a discussion of the impairment charges.

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Asset Retirement Obligations (Tables)

12 Months Ended

Dec. 31, 2021

Asset Retirement Obligations [Abstract]

Asset retirement obligation, roll forward analysis

A rollforward of NEE's and FPL's AROs is as follows:

	NEE			FPL
	(millions)
Balances, December 31, 2019	$	3,506		$	2,410
Liabilities incurred	138			—
Accretion expense	169			103
Liabilities settled	(53)			(32)
Revision in estimated cash flows – net	(594)		(a)	(545)		(a)
Balances, December 31, 2020	3,166		(b)	1,936		(b)
Liabilities incurred	79			7
Accretion expense	141			78
Liabilities settled	(88)		(c)	(15)
Revision in estimated cash flows – net	(119)		(d)	101		(e)
Balances, December 31, 2021	$	3,179	(b)	$	2,107	(b)

______________________

(a)Primarily reflects the effect of revised cost estimates for decommissioning FPL's nuclear units consistent with the updated nuclear decommissioning studies filed with the FPSC in December 2020.

(b)Includes the current portion of AROs as of December 31, 2021 and 2020 of approximately $97 million ($58 million for FPL) and $109 million ($65 million for FPL), respectively, which are included in other current liabilities on NEE's and FPL's consolidated balance sheets.

(c)Includes approximately $35 million related to project sales to NEP as well as other sales of businesses and assets. See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

(d)The increase at FPL discussed in (e) was offset primarily by the effect of revised cost estimates and useful lives of NEER's solar facilities.

(e)Primarily reflects the effect of pending license extension requests of St. Lucie Units Nos. 1 and 2 for an additional 20 years.

Funds restricted for decommissioning included in special use funds

Restricted funds for the payment of future expenditures to decommission NEE's and FPL's nuclear units included in special use funds on NEE's and FPL's consolidated balance sheets are presented below (see Note 4 – Special Use Funds). Duane Arnold is being actively decommissioned and was granted an exemption from the NRC, which allows for use of the funds for certain other site restoration activities in addition to decommissioning obligations recorded as AROs.

	NEE		FPL
	(millions)
Balances, December 31, 2021	$	8,846	$	6,082
Balances, December 31, 2020	$	7,703	$	5,271

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Employee Retirement Benefits (Tables)

12 Months Ended

Dec. 31, 2021

Retirement Benefits [Abstract]

Plan assets, benefit obligations, and funded status included in the consolidated balance sheets

Pension Plan Assets, Benefit Obligations and Funded Status – The changes in assets, benefit obligations and the funded status of the pension plan are as follows:

	2021		2020
	(millions)
Change in pension plan assets:
Fair value of plan assets at January 1	$	5,314	$	4,800
Actual return on plan assets	627		723
Benefit payments	(253)		(209)
Fair value of plan assets at December 31	$	5,688	$	5,314
Change in pension benefit obligation:
Obligation at January 1	$	3,607	$	3,363
Service cost	90		85
Interest cost	64		92
Special termination benefit(a)	—		16
Plan amendments	—		1
Actuarial losses (gains) – net	(63)		259
Benefit payments	(253)		(209)
Obligation at December 31(b)	$	3,445	$	3,607
Funded status:
Prepaid pension benefit costs at NEE at December 31	$	2,243	$	1,707
Prepaid pension benefit costs at FPL at December 31(c)	$	1,657	$	1,550

_________________________

(a)Reflects enhanced early retirement benefit.

(b)NEE's accumulated pension benefit obligation, which includes no assumption about future salary levels, at December 31, 2021 and 2020 was approximately $3,352 million and $3,521 million, respectively.

(c)Reflects FPL's allocated benefits under NEE's pension plan.

Unrecognized amounts included in accumulated other comprehensive income (loss)

NEE's unrecognized amounts included in accumulated other comprehensive income (loss) yet to be recognized as components of prepaid pension benefit costs are as follows:

	2021		2020
	(millions)
Unrecognized prior service benefit (net of $1 tax expense and $1 tax expense, respectively)	$	2	$	2
Unrecognized gains (losses) (net of $7 tax expense and $24 tax benefit, respectively)	41		(60)
Total	$	43	$	(58)

Unrecognized amounts included in regulatory assets (liabilities)

NEE's unrecognized amounts included in regulatory assets (liabilities) yet to be recognized as components of net prepaid pension benefit costs are as follows:

	2021		2020
	(millions)
Unrecognized prior service benefit	$	(1)	$	(1)
Unrecognized losses (gains)	(80)		163
Total	$	(81)	$	162

Significant assumptions used to determine benefit obligations and net periodic benefit (income) cost

The following table provides the assumptions used to determine the benefit obligation for the pension plan. These rates are used in determining net periodic pension income in the following year.

	2021		2020
Discount rate(a)	2.87	%	2.53	%
Salary increase	4.90	%	4.40	%
Weighted-average interest crediting rate	3.79	%	3.82	%

_________________________

(a)The method of estimating the interest cost component of net periodic benefit costs uses a full yield curve approach by applying a specific spot rate along the yield curve.

The assumptions used to determine net periodic pension income for the pension plan are as follows:

	2021		2020		2019
Discount rate	2.53	%	3.22	%	4.26	%
Salary increase	4.40	%	4.40	%	4.40	%
Expected long-term rate of return, net of investment management fees(a)	7.35	%	7.35	%	7.35	%
Weighted-average interest crediting rate	3.82	%	3.83	%	3.88	%

______________________

(a)In developing the expected long-term rate of return on assets assumption for its pension plan, NEE evaluated input, including other qualitative and quantitative factors, from its actuaries and consultants, as well as information available in the marketplace. 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. NEE also considered its pension fund's historical compounded returns.

Fair value measurements of pension plan assets by hierarchy level

The fair value measurements of NEE's pension plan assets by fair value hierarchy level are as follows:

	December 31, 2021(a)
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(millions)
Equity securities(b)	$	1,977	$	29	$	2	$	2,008
Equity commingled vehicles(c)	—		889		—		889
U.S. Government and municipal bonds	131		6		—		137
Corporate debt securities(d)	—		351		—		351
Asset-backed securities	—		386		—		386
Debt security commingled vehicles(e)	—		219		—		219
Convertible securities(f)	91		489		—		580
Total investments in the fair value hierarchy	$	2,199	$	2,369	$	2	4,570
Total investments measured at net asset value(g)							1,118
Total fair value of plan assets							$	5,688

_____________________

(a)See Notes 3 and 4 for discussion of fair value measurement techniques and inputs.

(b)Includes foreign investments of $927 million.

(c)Includes foreign investments of $169 million.

(d)Includes foreign investments of $109 million.

(e)Includes foreign investments of $5 million.

(f)Includes foreign investments of $41 million.

(g)Includes foreign investments of $220 million.

	December 31, 2020(a)
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(millions)
Equity securities(b)	$	2,017	$	10	$	3	$	2,030
Equity commingled vehicles(c)	—		668		—		668
U.S. Government and municipal bonds	169		8		—		177
Corporate debt securities(d)	—		340		—		340
Asset-backed securities	—		375		—		375
Debt security commingled vehicles(e)	—		201		—		201
Convertible securities(f)	64		453		—		517
Total investments in the fair value hierarchy	$	2,250	$	2,055	$	3	4,308
Total investments measured at net asset value(g)							1,006
Total fair value of plan assets							$	5,314

______________________

(a)See Notes 3 and 4 for discussion of fair value measurement techniques and inputs.

(b)Includes foreign investments of $881 million.

(c)Includes foreign investments of $156 million.

(d)Includes foreign investments of $93 million.

(e)Includes foreign investments of $5 million.

(f)Includes foreign investments of $35 million.

(g)Includes foreign investments of $153 million.

Expected benefit payments, net of government drug subsidy

Expected Cash Flows – The following table provides information about benefit payments expected to be paid by the pension plan for each of the following calendar years (in millions):

2022	$	204
2023	$	208
2024	$	209
2025	$	210
2026	$	214
2027 – 2031	$	1,033

Net periodic benefit (income) cost

Net Periodic Income – The components of net periodic income for the plans are as follows:

	Pension Benefits						Postretirement Benefits
	2021		2020		2019		2021		2020		2019
			(millions)
Service cost	$	90	$	85	$	80	$	2	$	1	$	1
Interest cost	64		92		114		4		8		9
Expected return on plan assets	(339)		(321)		(312)		—		—		—
Amortization of actuarial loss	24		18		—		5		3		—
Amortization of prior service benefit	(1)		(1)		(1)		(15)		(16)		(15)
Special termination benefits	—		16		19		—		—		—
Net periodic income at NEE	$	(162)	$	(111)	$	(100)	$	(4)	$	(4)	$	(5)
Net periodic income allocated to FPL	$	(108)	$	(84)	$	(61)	$	(4)	$	(4)	$	(4)

Components of net periodic benefit income (cost) recognized in OCI

Other Comprehensive Income – The components of net periodic income recognized in OCI for the pension plan are as follows:

	2021		2020		2019
	(millions)
Net gains (losses) (net of $29 tax expense, $13 tax expense and $10 tax benefit, respectively)	$	95	$	42	$	(36)
Amortization of unrecognized losses (net of $2 tax expense and $1 tax expense, respectively)	6		5		—
Total	$	101	$	47	$	(36)

Components of net periodic benefit (income) cost recognized in regulatory assets (liabilities)

Regulatory Assets (Liabilities) – The components of net periodic income recognized during the year in regulatory assets (liabilities) for the pension plan are as follows:

	2021		2020
	(millions)
Prior service cost (benefit)	$	(1)	$	1
Unrecognized gains	(226)		(89)
Amortization of prior service benefit	—		1
Amortization of unrecognized losses	(16)		(12)
Total	$	(243)	$	(99)

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Debt (Tables)

12 Months Ended

Dec. 31, 2021

Debt Disclosure [Abstract]

Debt Issuances and Borrowings by Subsidiaries

Long-term debt consists of the following:

	December 31,
	2021					2020
	Maturity Date	Balance		Weighted- Average Interest Rate		Balance			Weighted- Average Interest Rate
		(millions)				(millions)
FPL:
First mortgage bonds – fixed	2023 – 2051	$	14,290	4.20	%	$	13,090		4.32	%
Pollution control, solid waste disposal and industrial development revenue bonds – primarily variable(a)	2022 – 2050	1,407		0.15	%	1,407			0.17	%
Senior unsecured notes – primarily variable(b)(c)	2022 – 2071	2,697		1.37	%	2,621			1.55	%
Other long-term debt – variable(c)	2022 – 2046	307		0.82	%	300			0.70	%
Unamortized debt issuance costs and discount		(191)				(182)
Total long-term debt of FPL		18,510				17,236
Less current portion of long-term debt		536				354
Long-term debt of FPL, excluding current portion		17,974				16,882
NEER:
NextEra Energy Resources:
Senior secured limited-recourse long-term debt – variable(c)(d)	2024 – 2037	3,100		1.74	%	2,621			1.99	%
Senior secured limited-recourse long-term loans – fixed	2028 – 2049	2,475		3.30	%	704			3.59	%
Other long-term debt – primarily variable(c)(d)	2024 – 2048	785		2.50	%	450			2.72	%
NEET – long-term debt – primarily fixed(d)	2022 – 2049	1,151		2.69	%	937			3.09	%
Unamortized debt issuance costs and premium		(92)				(65)
Total long-term debt of NEER		7,419				4,647
Less current portion of long-term debt		664				239
Long-term debt of NEER, excluding current portion		6,755				4,408
NEECH:
Debentures – fixed	2023 – 2052	10,990		2.21	%	11,540		(d)	2.86	%
Debentures – variable(c)	2022 – 2023	3,850		0.56	%	1,225			0.80	%
Debentures, related to NEE's equity units – fixed	2024 – 2025	6,000		1.46	%	6,000			1.46	%
Junior subordinated debentures – primarily fixed(d)	2057 – 2082	3,723		4.54	%	3,693			4.78	%
Japanese yen denominated long-term debt – primarily variable(c)(d)(e)	2023 – 2030	582		1.49	%	650			1.49	%
Australian dollar denominated long-term debt – fixed(e)	2026	360		2.20	%	385			2.20	%
Other long-term debt – fixed	2022	186		0.92	%	221			0.92	%
Other long-term debt – variable(c)	2023 – 2024	1,245		0.64	%	600			0.70	%
Unamortized debt issuance costs, premium		(120)				(115)
Total long-term debt of NEECH		26,816				24,199
Less current portion of long-term debt		585				3,545
Long-term debt of NEECH, excluding current portion		26,231				20,654
Total long-term debt		$	50,960			$	41,944

______________________

(a)Includes variable rate tax exempt bonds that permit individual bondholders to tender the bonds for purchase at any time prior to maturity. In the event these variable rate tax exempt bonds are tendered for purchase, they would be remarketed by a designated remarketing agent in accordance with the related indenture. If the remarketing is unsuccessful, FPL would be required to purchase these variable rate tax exempt bonds. At December 31, 2021, these variable rate tax exempt bonds totaled approximately $1,375 million. All variable rate tax exempt bonds tendered for purchase have been successfully remarketed. FPL's syndicated revolving credit facilities are available to support the purchase of the variable rate tax exempt bonds. Variable interest rate is established at various intervals by the remarketing agent.

(b)At December 31, 2021, includes approximately $882 million of floating rate notes that permit individual noteholders to require repayment at specified dates prior to maturity. FPL’s syndicated revolving credit facilities are available to support the purchase of the floating rate notes.

(c)Variable rate is based on an underlying index plus a specified margin.

(d)Interest rate contracts, primarily swaps, have been entered into with respect to certain of these debt issuances. See Note 3.

(e)Foreign currency contracts have been entered into with respect to these debt issuances. See Note 3.

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Equity (Tables)

12 Months Ended

Dec. 31, 2021

Equity [Abstract]

Schedule of Earnings Per Share, Basic and Diluted

The reconciliation of NEE's basic and diluted earnings per share attributable to NEE is as follows:

	Years Ended December 31,
	2021		2020		2019
	(millions, except per share amounts)
Numerator – net income attributable to NEE	$	3,573	$	2,919	$	3,769
Denominator:
Weighted-average number of common shares outstanding – basic	1,962.5		1,959.0		1,927.9
Equity units, stock options, performance share awards and restricted stock(a)	9.7		9.8		14.0
Weighted-average number of common shares outstanding – assuming dilution	1,972.2		1,968.8		1,941.9
Earnings per share attributable to NEE:
Basic	$	1.82	$	1.49	$	1.95
Assuming dilution	$	1.81	$	1.48	$	1.94

______________________

(a)Calculated using the treasury stock method. Performance share awards are included in diluted weighted-average number of common shares outstanding based upon what would be issued if the end of the reporting period was the end of the term of the award.

Nonvested Awards Activity

The activity in restricted stock and performance share awards for the year ended December 31, 2021 was as follows:

	Shares/Units	Weighted- Average Grant Date Fair Value Per Share/Units
Restricted Stock:
Nonvested balance, January 1, 2021	1,674,242	$	50.26
Granted	1,013,039	$	82.69
Vested	(835,919)	$	48.06
Forfeited	(33,630)	$	69.63
Nonvested balance, December 31, 2021	1,817,732	$	68.09
Performance Share Awards:
Nonvested balance, January 1, 2021	1,938,608	$	47.46
Granted	1,297,680	$	54.82
Vested	(1,738,904)	$	37.53
Forfeited	(85,235)	$	64.84
Nonvested balance, December 31, 2021	1,412,149	$	61.22

Assumptions used to estimate fair value of options

The fair value of the options is estimated on the date of the grant using the Black-Scholes option-pricing model and based on the following assumptions:

	2021	2020	2019
Expected volatility(a)	17.32 – 17.75%	14.63 – 16.31%	14.20 – 14.31%
Expected dividends	2.30 – 2.44%	2.50 – 2.72%	2.85 – 2.93%
Expected term (years)(b)	7.0	7.0	7.0
Risk-free rate	0.80 – 1.27%	0.49 – 1.52%	2.24 – 2.54%

______________________

(a)Based on historical experience.

(b)Based on historical exercise and post-vesting cancellation experience adjusted for outstanding awards.

Stock option activity

Option activity for the year ended December 31, 2021 was as follows:

	Shares Underlying Options	Weighted- Average Exercise Price Per Share		Weighted- Average Remaining Contractual Term (years)	Aggregate Intrinsic Value (millions)
Balance, January 1, 2021	9,618,204	$	38.32
Granted	1,220,265	$	83.33
Exercised	(738,516)	$	20.08
Forfeited	(86,641)	$	71.19
Balance, December 31, 2021	10,013,312	$	44.87	6.0	$	486
Exercisable, December 31, 2021	7,235,572	$	35.35	5.0	$	420

Schedule of Accumulated Other Comprehensive Income (Loss)

The components of AOCI, net of tax, are as follows:

	Accumulated Other Comprehensive Income (Loss)
	Net Unrealized Gains (Losses) on Cash Flow Hedges			Net Unrealized Gains (Losses) on Available for Sale Securities			Defined Benefit Pension and Other Benefits Plans			Net Unrealized Gains (Losses) on Foreign Currency Translation			Other Comprehensive Income (Loss) Related to Equity Method Investees		Total
	(millions)
Balances, December 31, 2018	$	(55)		$	(7)		$	(65)		$	(63)		$	2	$	(188)
Other comprehensive income (loss) before reclassifications	—			20			(46)			22			1		(3)
Amounts reclassified from AOCI	29		(a)	(2)		(b)	(3)		(c)	—			—		24
Net other comprehensive income (loss)	29			18			(49)			22			1		21
Less other comprehensive income attributable to noncontrolling interests	—			—			—			1			—		1
Acquisition of Gulf Power (see Note 6)	(1)			—			—			—			—		(1)
Balances, December 31, 2019	(27)			11			(114)			(42)			3		(169)
Other comprehensive income before reclassifications	—			12			37			13			1		63
Amounts reclassified from AOCI	12		(a)	(3)		(b)	2		(c)	—			—		11
Net other comprehensive income	12			9			39			13			1		74
Less other comprehensive income attributable to noncontrolling interests	—			—			—			7			—		7
Impact of disposal of a business	23		(d)	—			—			(13)		(d)	—		10
Balances, December 31, 2020	8			20			(75)			(49)			4		(92)
Other comprehensive income (loss) before reclassifications	—			(11)			95			(1)			1		84
Amounts reclassified from AOCI	6		(a)	(4)		(b)	5		(c)	—			—		7
Net other comprehensive income (loss)	6			(15)			100			(1)			1		91
Less other comprehensive loss attributable to noncontrolling interests	—			—			—			(1)			—		(1)
Balances, December 31, 2021	$	14		$	5		$	25		$	(49)		$	5	$	—
Attributable to noncontrolling interests	$	—		$	—		$	—		$	6		$	—	$	6

______________________

(a)Reclassified to interest expense in NEE's consolidated statements of income. See Note 3 – Income Statement Impact of Derivative Instruments.

(b)Reclassified to gains on disposal of investments and other property – net in NEE's consolidated statements of income.

(c)Reclassified to other net periodic benefit income in NEE's consolidated statements of income.

(d)Reclassified to gains on disposal of businesses/assets – net and interest expense in NEE's consolidated statements of income. See Note 3 – Income Statement Impact of Derivative Instruments and Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

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Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

Schedule of Planned Capital Expenditures

At December 31, 2021, estimated capital expenditures for 2022 through 2026 were as follows:

	2022		2023		2024		2025		2026		Total
	(millions)
FPL:
Generation:(a)
New(b)	$	1,825	$	1,670	$	1,635	$	1,210	$	995	$	7,335
Existing	1,605		1,465		1,220		685		750		5,725
Transmission and distribution(c)	4,035		3,760		3,870		4,760		5,075		21,500
Nuclear fuel	155		110		145		145		120		675
General and other	875		625		715		740		665		3,620
Total	$	8,495	$	7,630	$	7,585	$	7,540	$	7,605	$	38,855
NEER:(d)
Wind(e)	$	2,630	$	240	$	50	$	35	$	30	$	2,985
Solar(f)	3,445		1,010		170		25		10		4,660
Battery storage	270		120		—		—		5		395
Nuclear, including nuclear fuel	200		150		200		210		210		970
Rate-regulated transmission	220		85		55		30		30		420
Other	440		85		95		60		70		750
Total	$	7,205	$	1,690	$	570	$	360	$	355	$	10,180

______________________

(a)Includes AFUDC of approximately $75 million, $85 million, $60 million, $50 million and $40 million for 2022 through 2026, respectively.

(b)Includes land, generation structures, transmission interconnection and integration and licensing.

(c)Includes AFUDC of approximately $50 million, $45 million, $40 million, $15 million and $0 million for 2022 through 2026, respectively.

(d)Represents capital expenditures for which applicable internal approvals and also, if required, regulatory approvals have been received.

(e)Consists of capital expenditures for new wind projects, repowering of existing wind projects and related transmission totaling approximately 2,852 MW.

(f)Includes capital expenditures for new solar projects (including solar plus battery storage projects) and related transmission totaling approximately 5,946 MW.

Required Capacity and/or Minimum Payments

The required capacity and/or minimum payments under contracts, including those discussed above at December 31, 2021, were estimated as follows:

	2022		2023		2024		2025		2026		Thereafter
	(millions)
FPL(a)	$	1,025	$	980	$	955	$	900	$	825	$	8,570
NEER(b)(c)(d)	$	4,400	$	365	$	185	$	85	$	65	$	570

_______________________

(a)Includes approximately $415 million, $410 million, $410 million, $405 million, $400 million and $5,960 million in 2022 through 2026 and thereafter, respectively, of firm commitments related to the natural gas transportation agreements with Sabal Trail and Florida Southeast Connection, LLC. The charges associated with these agreements are recoverable through the fuel clause and totaled approximately $419 million, $386 million and $316 million for the years ended December 31, 2021, 2020 and 2019, respectively, of which $105 million, $108 million and $108 million, respectively, were eliminated in consolidation at NEE.      

(b)Excludes commitments related to equity contributions and a 20-year natural gas transportation agreement (approximately $70 million per year) with a joint venture, in which NEER has a 31.9% equity investment, that is constructing a natural gas pipeline. These commitments are subject to the completion of construction of the pipeline which has a very low probability of completion. See Note 4 – Nonrecurring Fair Value Measurements.

(c)Includes approximately $370 million of commitments to invest in technology and other investments through 2031. See Note 9 – Other.

(d)Includes approximately $610 million, $20 million, $5 million, $5 million, $0 million and $5 million for 2022 through 2026 and thereafter, respectively, of joint obligations of NEECH and NEER.

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Segment Information (Tables)

12 Months Ended

Dec. 31, 2021

Segment Reporting [Abstract]

Segment Information

NEE's segment information is as follows:

	2021
	FPL Segment		Gulf Power		NEER(a)		Corp. and Other		NEE Consolidated
	(millions)
Operating revenues	$	12,600	$	1,503	$	3,053	$	(87)	$	17,069
Operating expenses – net	$	8,418	$	1,170	$	4,434	$	211	$	14,233
Gains (losses) on disposal of businesses/assets – net	$	1	$	—	$	78	$	(2)	$	77
Interest expense	$	588	$	28	$	367	$	287	$	1,270
Depreciation and amortization	$	1,968	$	297	$	1,576	$	83	$	3,924
Equity in earnings of equity method investees	$	—	$	—	$	666	$	—	$	666
Income tax expense (benefit)(b)	$	767	$	71	$	(395)	$	(95)	$	348
Net income (loss)	$	2,935	$	271	$	(147)	$	(232)	$	2,827
Net income (loss) attributable to NEE	$	2,935	$	271	$	599	$	(232)	$	3,573
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	6,785	$	782	$	8,363	$	147	$	16,077
Property, plant and equipment – net	$	52,728	$	5,499	$	40,900	$	221	$	99,348
Total assets	$	68,197	$	7,209	$	62,113	$	3,393	$	140,912
Investment in equity method investees	$	—	$	—	$	6,150	$	9	$	6,159

	2020
	FPL Segment		Gulf Power		NEER(a)		Corp. and Other		NEE Consolidated
	(millions)
Operating revenues	$	11,662	$	1,398	$	5,046	$	(109)	$	17,997
Operating expenses – net	$	7,862	$	1,081	$	4,125	$	166	$	13,234
Gains (losses) on disposal of businesses/assets – net	$	—	$	—	$	363	$	(10)	$	353
Interest expense	$	600	$	41	$	659	$	650	$	1,950
Depreciation and amortization	$	2,246	$	281	$	1,460	$	65	$	4,052
Equity in losses of equity method investees	$	—	$	—	$	(1,351)	$	—	$	(1,351)
Income tax expense (benefit)(b)	$	610	$	67	$	(416)	$	(217)	$	44
Net income (loss)	$	2,650	$	238	$	(19)	$	(500)	$	2,369
Net income (loss) attributable to NEE	$	2,650	$	238	$	531	$	(500)	$	2,919
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	6,680	$	1,012	$	6,893	$	25	$	14,610
Property, plant and equipment – net	$	48,933	$	4,946	$	37,842	$	82	$	91,803
Total assets	$	61,610	$	6,725	$	55,633	$	3,716	$	127,684
Investment in equity method investees	$	—	$	—	$	5,713	$	15	$	5,728

_________________________

(a)Interest expense allocated from NEECH is based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy Resources' subsidiaries. Residual NEECH corporate interest expense is included in Corporate and Other.

(b)NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 – Income Taxes.

	2019
	FPL Segment		Gulf Power		NEER(a)		Corp. and Other		NEE Consolidated
	(millions)
Operating revenues	$	12,192	$	1,487	$	5,639	$	(114)	$	19,204
Operating expenses – net	$	8,895	$	1,216	$	4,037	$	109	$	14,257
Gains (losses) on disposal of businesses/assets – net	$	5	$	—	$	402	$	(1)	$	406
Interest expense	$	594	$	55	$	873	$	727	$	2,249
Depreciation and amortization	$	2,524	$	247	$	1,387	$	58	$	4,216
Equity in earnings (losses) of equity method investees	$	—	$	—	$	67	$	(1)	$	66
Income tax expense (benefit)(b)	$	441	$	42	$	162	$	(197)	$	448
Net income (loss)	$	2,334	$	180	$	1,426	$	(552)	$	3,388
Net income (loss) attributable to NEE	$	2,334	$	180	$	1,807	$	(552)	$	3,769
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	5,755	$	729	$	6,505	$	4,473	$	17,462
Property, plant and equipment – net	$	45,074	$	4,763	$	32,042	$	131	$	82,010
Total assets	$	57,188	$	5,855	$	51,516	$	3,132	$	117,691
Investment in equity method investees	$	—	$	—	$	7,453	$	—	$	7,453

_________________________

(a)Interest expense allocated from NEECH is based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy Resources' subsidiaries. Residual NEECH corporate interest expense is included in Corporate and Other.

(b)NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 – Income Taxes.

FPL's segment information is as follows:

	2021								2020								2019
	FPL Segment		Gulf Power		Corp. and Other		FPL Consoli- dated		FPL Segment		Gulf Power		Corp. and Other		FPL Consoli-dated		FPL Segment		Gulf Power		Corp. and Other		FPL Consoli-dated
	(millions)
Operating revenues	$	12,600	$	1,503	$	(1)	$	14,102	$	11,662	$	1,398	$	—	$	13,060	$	12,192	$	1,487	$	1	$	13,680
Operating expenses – net (a)	$	8,418	$	1,170	$	(2)	$	9,586	$	7,862	$	1,081	$	(3)	$	8,940	$	8,895	$	1,216	$	(10)	$	10,101
Interest expense	$	588	$	28	$	(1)	$	615	$	600	$	41	$	—	$	641	$	594	$	55	$	—	$	649
Depreciation and amortization	$	1,968	$	297	$	1	$	2,266	$	2,246	$	281	$	(1)	$	2,526	$	2,524	$	247	$	—	$	2,771
Income tax expense	$	767	$	71	$	—	$	838	$	610	$	67	$	1	$	678	$	441	$	42	$	1	$	484
Net income	$	2,935	$	271	$	—	$	3,206	$	2,650	$	238	$	2	$	2,890	$	2,334	$	180	$	5	$	2,519
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	6,785	$	782	$	3	$	7,570	$	6,680	$	1,012	$	(13)	$	7,679	$	5,755	$	729	$	1	$	6,485
Property, plant and equipment – net	$	52,728	$	5,499	$	—	$	58,227	$	48,933	$	4,946	$	—	$	53,879	$	45,074	$	4,763	$	—	$	49,837
Total assets	$	68,197	$	7,209	$	2,661	$	78,067	$	61,610	$	6,725	$	2,666	$	71,001	$	57,188	$	5,855	$	2,647	$	65,690

_________________________

(a)FPL's income statement line for total operating expenses – net includes gains (losses) on disposal of businesses/assets – net.

XML

Summary of Significant Accounting and Reporting Policies (Additional Information) (Details) € in Millions, account in Millions, $ in Millions		1 Months Ended			12 Months Ended
	Oct. 29, 2021 USD ($) facility MW	Dec. 31, 2021 USD ($) facility account county MW	Dec. 31, 2020 USD ($) facility MW		Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($) facility county account unit MW	Dec. 31, 2020 USD ($) facility solar_generation_facility MW		Dec. 31, 2019 USD ($) solar_generation_facility wind_generation_facility MW	Dec. 31, 2020 EUR (€) facility	Jan. 01, 2020 USD ($)
Basis of Presentation [Abstract]
Number of customer accounts (more than) | account		5.7				5.7
Number of counties In which entity operates | county		8				8
Regulated and Unregulated Operating Revenue [Abstract]
Revenue from contracts with customers						$ 18,800	$ 17,000		$ 17,500
Electric Plant, Depreciation and Amortization [Abstract]
Convertible ITCs						755	791
Construction Activity [Abstract]
Impairment charges									72
Impairment of long-lived assets, after tax									54
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Asset Retirement Obligation		$ 3,179	$ 3,166			3,179	3,166		3,506
Restricted Cash [Abstract]
Restricted cash, current		677	441			677	441
Restricted cash related to margin cash collateral that is netted against derivative assets		121	183			121	183
Restricted cash related to margin cash collateral that is netted against derivative liabilities		172	136			172	136
Measurement of Credit Losses on Financial Instruments [Abstract]
Retained earnings		25,911	25,363			25,911	25,363
Accounts Receivable, Credit Loss Expense (Reversal)						146	94		32
Accounts Receivable, Allowance for Credit Loss, Noncurrent		127				127
Income Taxes [Abstract]
Revenue equivalent of the difference in accumulated deferred income taxes computed under accounting rules, as compared to regulatory accounting rules		3,780	3,949			$ 3,780	3,949
Amortization period						5 years
Unrecognized tax benefits that impact annual effective income tax rate		125				$ 125
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal						77	353		406
Customer deposits		485	474			485	474
Construction Costs		1,378	991			$ 1,378	991
St. Lucie Units Number One
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
License renewal period						20 years
St. Lucie Units Number Two
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
License renewal period						20 years
Accounting Standards Update 2016-13 [Member]
Measurement of Credit Losses on Financial Instruments [Abstract]
Retained earnings											$ 11
FPL [Member]
Regulated and Unregulated Operating Revenue [Abstract]
Revenue from contracts with customers						$ 14,100	13,000		13,600
Electric Plant, Depreciation and Amortization [Abstract]
Convertible ITCs						$ 116	$ 122
Construction Activity [Abstract]
Threshold of plant in service balance at which AFUDC may be recorded (in hundredths)						0.40%	0.50%
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Maximum interval between nuclear decommissioning studies submitted to the FPSC for approval (in years)						5 years
For FPL, number of nuclear units | unit						4
FPL's portion of the ultimate costs of nuclear decommissioning		10,200				$ 10,200
FPL's Ultimate costs of nuclear decommissioning, in current year dollars		2,400				2,400
FPL's fund earnings on decommissioning funds						173	$ 132		125
Plant Dismantlement Approved Expense						26
Ultimate Costs Of Plant Dismantlement		2,500				2,500
Ultimate Costs Of Plant Dismantlement In Current Year Dollars		1,200				1,200
Asset Retirement Obligation		2,107	1,936			2,107	1,936		$ 2,410
Restricted Cash [Abstract]
Restricted cash, current		53	135			53	135
Measurement of Credit Losses on Financial Instruments [Abstract]
Retained earnings		12,285	9,619	[1]		12,285	9,619	[1]
Storm Funds Storm Reserves and Storm Cost Recovery Abstract
Storm restoration costs		242	347			242	347
Income Taxes [Abstract]
Revenue equivalent of the difference in accumulated deferred income taxes computed under accounting rules, as compared to regulatory accounting rules		3,723	3,890			3,723	3,890
Accumulated Deferred Investment Tax Credit		1,054	753			1,054	753
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Customer deposits		478	468	[1]		478	468	[1]
Construction Costs		601	423	[1]		$ 601	423	[1]
FPL [Member] | St. Lucie Units Number One
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
License renewal period						20 years
FPL [Member] | St. Lucie Units Number Two
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
License renewal period						20 years
NEER [Member]
Construction Activity [Abstract]
Project development costs of NextEra Energy Resources		$ 831	571			$ 831	571
Deemed capital structure of NextEra Energy Resources (in hundredths)		70.00%				70.00%
Wind Electric Generating Facility Capability | MW									220
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Asset Retirement Obligation		$ 1,100	1,200			$ 1,100	1,200
Ultimate Costs Of Nuclear Decommissioning For Wholly Owned Indirect Subsidiary		9,400				9,400
Ultimate Costs Of Nuclear Decommissioning In Current Year Dollars For Wholly Owned Indirect Subsidiary		2,100				2,100
Ultimate costs to dismantle wind and solar facilities						$ 2,000
Effective period for Seabrook's decommissioning funding plan (in years)						4 years
Variable Interest Entities [Abstract]
Wind Electric Generating Facility Capability | MW									220
NEER [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Construction Activity [Abstract]
Wind Electric Generating Facility Capability | MW						11,226
Variable Interest Entities [Abstract]
Wind Electric Generating Facility Capability | MW						11,226
Solar generating facility capability | MW						1,894
Battery Storage Facility Capability [Line Items] | MW						220
Forecast [Member] | FPL [Member]
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Plant Dismantlement Approved Expense					$ 48
Current other assets
Restricted Cash [Abstract]
Restricted cash, current		677	374			$ 677	374
Current other assets | FPL [Member]
Restricted Cash [Abstract]
Restricted cash, current		53	93			53	93
Regulatory Assets, Current | FPL [Member]
Storm Funds Storm Reserves and Storm Cost Recovery Abstract
Storm restoration costs		92	100			92	100
Regulatory Assets, Noncurrent | FPL [Member]
Storm Funds Storm Reserves and Storm Cost Recovery Abstract
Storm restoration costs		150	247			150	247
Franchise and Gross Receipts Taxes [Member]
Regulated and Unregulated Operating Revenue [Abstract]
Revenue from contracts with customers						852	800		$ 838
Franchise and Gross Receipts Taxes [Member] | FPL [Member]
Regulated and Unregulated Operating Revenue [Abstract]
Revenue from contracts with customers						852	800		838
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Two solar generation facilities located in Spain [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal							270
Disposal Group, Not Discontinued Operation, Gain (Loss) On Disposal, Net Of Tax							$ 270
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Two solar generation facilities located in Spain [Member] | NEER [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Total generating facility capacity (mw) | MW							99.8
Disposal Group, Including Discontinued Operation, Consideration			$ 121				$ 121			€ 111
Number Of Generation Facilities Sold | solar_generation_facility							2
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three Wind Generation Facilities And Three Solar Generation Facilities [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal									341
Disposal Group, Not Discontinued Operation, Gain (Loss) On Disposal, Net Of Tax									259
Disposal Group, Including Discontinued Operation, Stockholders' Equity Attributable to Noncontrolling Interest									$ 118
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three Wind Generation Facilities And Three Solar Generation Facilities [Member] | NEER [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Total generating facility capacity (mw) | MW									611
Disposal Group, Including Discontinued Operation, Consideration									$ 1,000
Disposal Group, Including Discontinued Operation, Working Capital									$ 12
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Solar plants [Member] | NEER [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Number Of Generation Facilities Sold | solar_generation_facility									3
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Solar plants [Member] | Noncontrolling Interest [Member] | NEER [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Number Of Generation Facilities Sold | solar_generation_facility									2
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Wind plants [Member] | NEER [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Number Of Generation Facilities Sold | wind_generation_facility									3
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind facilities and one solar facility | subsidiary of NextEra Energy Resources [Member] | United States, Midwest and West Regions
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Number Of Wind Generation Facilities | facility	3
Number Solar Generation Facilities | facility	1
Total generating facility capacity (mw) | MW	467
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind facilities and one solar facility | subsidiary of NextEra Energy Resources [Member] | NEP [Member] | United States, Midwest and West Regions
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold	100.00%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Four solar facilities and multiple generation solar facilities | subsidiary of NextEra Energy Resources [Member] | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Number Solar Generation Facilities | facility	4
Total generating facility capacity (mw) | MW	122
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Four solar facilities and multiple generation solar facilities | subsidiary of NextEra Energy Resources [Member] | NEP [Member] | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold	33.30%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and one solar facility and four solar facilities and multiple distributed generation solar facilities
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal						94
Disposal Group, Not Discontinued Operation, Gain (Loss) On Disposal, Net Of Tax						69
Disposal Group, Including Discontinued Operation, Stockholders' Equity Attributable to Noncontrolling Interest		125				125
Increase (Decrease) To Additional Paid In Capital, Gross		60				60
Increase (Decrease) To Additional Paid In Capital, Net		43				$ 43
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and one solar facility and four solar facilities and multiple distributed generation solar facilities | NEER [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Including Discontinued Operation, Consideration	$ 563
Disposal Group, Including Discontinued Operation, Working Capital	$ 22
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Seven wind facilities, six solar facilities and storage capacity
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal		53
Disposal Group, Not Discontinued Operation, Gain (Loss) On Disposal, Net Of Tax		$ 33
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Seven wind facilities, six solar facilities and storage capacity | subsidiary of NextEra Energy Resources [Member] | Third Party [Member] | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold		50.00%				50.00%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Seven wind facilities, six solar facilities and storage capacity | subsidiary of NextEra Energy Resources [Member] | NEP [Member] | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold		50.00%				50.00%
Number Of Wind Generation Facilities | facility		7				7
Number Solar Generation Facilities | facility		6				6
Battery Storage Facility Capacity | MW		115
Total generating facility capacity (mw) | MW		2,520
Disposal Group, Including Discontinued Operation, Consideration		$ 1,700				$ 1,700
Customer deposits		668				668
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Seven wind facilities, six solar facilities and storage capacity | subsidiary of NextEra Energy Resources [Member] | NEP And Third Party | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Customer deposits		349				349
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Seven wind facilities, six solar facilities and storage capacity | subsidiary of NextEra Energy Resources [Member] | Differential Memberships | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Customer deposits		319				319
Disposal of Business and Interest Affiliates, Contingent Payments		117				117
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and four solar generation facilities | subsidiary of NextEra Energy Resources [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Number Of Wind Generation Facilities | facility			3				3			3
Number Solar Generation Facilities | facility			4				4			4
Total generating facility capacity (mw) | MW			900
Disposal Group, Including Discontinued Operation, Stockholders' Equity Attributable to Noncontrolling Interest			$ 689				$ 689
Increase (Decrease) To Additional Paid In Capital, Gross			(188)				(188)
Increase (Decrease) To Additional Paid In Capital, Net			$ (165)				$ (165)
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and four solar generation facilities | subsidiary of NextEra Energy Resources [Member] | Third Party [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold			50.00%				50.00%			50.00%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and four solar generation facilities | subsidiary of NextEra Energy Resources [Member] | subsidiary of NextEra Energy Resources [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold			90.00%				90.00%			90.00%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and four solar generation facilities | subsidiary of NextEra Energy Resources [Member] | NEP [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold			40.00%				40.00%			40.00%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | One solar generation facility and one battery storage facility
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Solar Generating Capacity | MW			100
Solar Plus Storage Facility Capacity | MW			30
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | One solar generation facility and one battery storage facility | subsidiary of NextEra Energy Resources [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Customer deposits			$ 155				$ 155
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | One solar generation facility and one battery storage facility | subsidiary of NextEra Energy Resources [Member] | Solar-Plus-Storage Facility [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold			100.00%				100.00%			100.00%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and four solar facilities and one solar facilities and multiple distributed generation solar facilities | NEER [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Including Discontinued Operation, Consideration			$ 656				$ 656
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Accounts Payable | Seven wind facilities, six solar facilities and storage capacity
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Construction Costs		$ 970				$ 970

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

XML

Summary of Significant Accounting and Reporting Policies (FPL Base Rate Agreements) (Details) - FPL [Member]						12 Months Ended			48 Months Ended	60 Months Ended
	Jan. 01, 2023 USD ($)	Jan. 01, 2022 USD ($)	Apr. 01, 2019 USD ($) MW	Jan. 01, 2018 USD ($)	Jan. 01, 2017 USD ($)	Dec. 31, 2025 MW	Dec. 31, 2024 MW	Dec. 31, 2022 USD ($)	Dec. 31, 2025 USD ($) kWh $ / kW MW	Dec. 31, 2021 USD ($)	Dec. 31, 2020 MW
Accounting Policies [Line Items]
Increase in base rate revenues			$ 200,000,000	$ 211,000,000	$ 400,000,000
Regulatory return on common equity										10.55%
Earned regulatory ROE threshold below which retail base rate relief may be sought										9.60%
Earned regulatory ROE threshold above which retail base rate reduction may be sought										11.60%
Energy Assets, Power Generation Capacity | MW			1,720
Renewable energy assets, power generation capacity (mw) | MW											1,200
The maximum amount by which depreciation expense could be reduced (reserve)										$ 1,250,000,000
Forecast [Member]
Accounting Policies [Line Items]
Increase in base rate revenues	$ 560,000,000	$ 692,000,000
SoBRA MW additions capacity | MW						894	894
SoBRA base rate revenue installed solar cap cost per unit of power | $ / kW									1,250
Regulatory return on common equity									10.60%
Earned regulatory ROE threshold below which retail base rate relief may be sought									9.70%
Earned regulatory ROE threshold above which retail base rate reduction may be sought									11.70%
Contingent ROE, treasury rate, thirty year average threshold									2.49%
Contingent ROE, consecutive term									6 months
Contingent return on common equity									10.80%
Contingent earned regulatory ROE threshold below which retail base rate relief may be sought									9.80%
Contingent earned regulatory ROE threshold above which retail base rate reduction may be sought									11.80%
Maximum amount of depreciation reserve that may be amortized								$ 200,000,000	$ 1,450,000,000
SolarTogether MW additions capacity | MW									1,788
SolarTogether MW total capacity | MW						3,278
Time period after filing of a cost recovery petition that future storm restoration costs would be recoverable on an interim basis									60 days
Maximum storm surcharge									$ 4
Increment of usage in Kwh on which storm surcharge is based | kWh									1,000
Cost of recovery, period									12 months
Threshold of storm restoration costs in any given calendar year at which surcharge may be increased									$ 800,000,000

XML

Summary of Significant Accounting and Reporting Policies (Regulatory Assets and Liabilities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Current:
Early retirement of generation facilities and transmission assets	$ 140	$ 36
Acquisition of purchased power agreements	141	161
Deferred clause and franchise expenses	698	28
Other	146	152
Total	1,125	377
Noncurrent:
Acquisition of purchased power agreements	2,233	1,438
Acquisition of purchased power agreements	332	473
Accrued asset removal costs	263	0
Other	1,750	1,801
Total	4,578	3,712
Current:
Deferred clause revenues	274	215
Other	15	30
Total	289	245
Noncurrent:
Asset retirement obligation regulatory expense difference	4,290	3,583
Accrued asset removal costs	782	1,206
Deferred taxes	4,561	4,698
Other	1,640	1,248
Total	11,273	10,735
FPL [Member]
Current:
Early retirement of generation facilities and transmission assets	140	36
Acquisition of purchased power agreements	141	161
Deferred clause and franchise expenses	698	28
Other	132	135
Total	1,111	360	[1]
Noncurrent:
Acquisition of purchased power agreements	2,233	1,438
Acquisition of purchased power agreements	332	473
Accrued asset removal costs	263	0
Other	1,515	1,488
Total	4,343	3,399	[1]
Current:
Deferred clause revenues	274	215
Other	4	9
Total	278	224	[1]
Noncurrent:
Asset retirement obligation regulatory expense difference	4,290	3,583
Accrued asset removal costs	752	1,179
Deferred taxes	4,457	4,594
Other	1,554	1,244
Total	$ 11,053	$ 10,600
Generation Facilities And Transmission Assets
Noncurrent:
Regulatory asset, amortization period	20 years
Purchased Power Agreements
Noncurrent:
Regulatory asset, amortization period	9 years

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

XML

Summary of Significant Accounting and Reporting Policies (Goodwill and Intangible Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020		Dec. 31, 2019
Goodwill and Intangible Assets [Line Items]
Goodwill	$ 4,844	$ 4,254
Other intangible assets not subject to amortization, primarily land easements	136	135
Other intangible assets:
Total	694	619
Accumulated amortization	(88)	(61)
Total other intangible assets subject to amortization - net	606	558
Intangible assets, amortization [Abstract]
Amortization expense	25	27		$ 18
Amortization Expense Year 1	16
Amortization Expense Year 2	16
Amortization Expense Year 3	18
Amortization Expense Year 4	16
Amortization Expense Year 5	$ 16
Purchased Power Agreements [Member]
Other intangible assets:
Weighted average useful lives (years)	15 years
Total	$ 507	453
Other, primarily transmission and development rights and customer lists [Member]
Other intangible assets:
Weighted average useful lives (years)	23 years
Total	$ 187	166
Rate-Regulated Transmission [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	1,206	614
Gas Infrastructure, primarily Texas pipelines [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	487	487
Customer Supply [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	95	93
Generation Assets [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	56	60
Other Goodwill Assets [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	11	11
FPL [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	2,989	2,989	[1]
FPL [Member] | Florida City Gas [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	292	292
FPL [Member] | Other Goodwill Assets [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	9	9
Gulf Power [Member] | Other Goodwill Assets [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	$ 2,688	$ 2,688

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

XML

Revenue from Contracts with Customers (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 18,800	$ 17,000	$ 17,500
FPL [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	14,100	13,000	$ 13,600
Unbilled revenues	583	$ 454
Revenue, remaining performance obligation	$ 400
FPL [Member] | Revenue Benchmark [Member] | Customer Concentration Risk | Retail Customer
Disaggregation of Revenue [Line Items]
Concentration risk, percentage	90.00%
NEER [Member]
Disaggregation of Revenue [Line Items]
Revenue not recognized	$ 180
Revenue, remaining performance obligation	$ 735

XML

Derivative Instruments (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ (6,000,000)
Derivative, Collateral, Obligation to Return Cash	56,000,000	$ 6,000,000
Margin Cash Collateral Not Netted Against Derivative Liabilities	673,000,000	315,000,000
Reclassification from AOCI, Current Period, before Tax, Attributable to Parent		26,000,000	$ 11,000,000
Reclassification from AOCI, Current Period, Net of Tax, Attributable to Parent		6,000,000	$ 8,000,000
FPL [Member]
Derivative [Line Items]
Derivative, Collateral, Obligation to Return Cash	0	0
Margin Cash Collateral Not Netted Against Derivative Liabilities	$ 0	0
Interest rate contracts | Not Designated as Hedging Instrument [Member] | Gains (Loss) On Disposal Of Businesses/Assets - Net [Member]
Derivative [Line Items]
Reclassification from AOCI, Current Period, before Tax, Attributable to Parent		$ 23,000,000

XML

Derivative Instruments (Balance Sheet Disclosure) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets	$ 1,824	$ 2,217
Derivative Liabilities	2,976	1,510
Derivative Asset, Current	689	570
Derivative Asset, Noncurrent	1,135	1,647
Derivative Liability, Current	1,263	311
Derivative Liability, Noncurrent	1,713	1,199
Current derivative assets
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Margin cash collateral received from counterparties	150
Non Current Derivative Assets Member
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Margin cash collateral received from counterparties	56	184
Current derivative liabilities
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Margin cash collateral paid to counterparties	6	136
Noncurrent derivative liabilities
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Margin cash collateral paid to counterparties	172
Commodity contracts | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative assets, Netting	(6,622)	(2,325)
Derivative liability, Netting	(6,594)	(2,277)
Derivative Assets	1,757	2,154
Derivative Liabilities	2,198	500
Commodity contracts | Level 1 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	1,896	919
Total derivative liabilities	2,571	1,004
Commodity contracts | Level 2 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	5,082	1,881
Total derivative liabilities	4,990	1,468
Commodity contracts | Level 3 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	1,401	1,679
Total derivative liabilities	1,231	305
Interest rate contracts | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative assets, Netting	(30)	(41)
Derivative liability, Netting	(30)	(41)
Derivative Assets	76	40
Derivative Liabilities	709	1,001
Interest rate contracts | Level 1 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	0	0
Total derivative liabilities	0	0
Interest rate contracts | Level 2 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	106	81
Total derivative liabilities	739	1,042
Interest rate contracts | Level 3 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	0	0
Total derivative liabilities	0	0
Foreign currency contracts | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative assets, Netting	(17)	(34)
Derivative liability, Netting	(17)	(34)
Derivative Assets	(9)	23
Derivative Liabilities	69	9
Foreign currency contracts | Level 1 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	0	0
Total derivative liabilities	0	0
Foreign currency contracts | Level 2 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	8	57
Total derivative liabilities	86	43
Foreign currency contracts | Level 3 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	0	0
Total derivative liabilities	0	0
FPL [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Liabilities	10	3
FPL [Member] | Current other assets
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Current	13	3
FPL [Member] | Current other liabilities
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Liability, Current	9	2
FPL [Member] | Noncurrent other liabilities
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Liability, Noncurrent	1	1
FPL [Member] | Commodity contracts | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative assets, Netting	(3)	0
Derivative liability, Netting	(3)	0
Derivative Assets	13	3
Derivative Liabilities	10	3
FPL [Member] | Commodity contracts | Level 1 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	0	0
Total derivative liabilities	0	0
FPL [Member] | Commodity contracts | Level 2 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	3	1
Total derivative liabilities	8	0
FPL [Member] | Commodity contracts | Level 3 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	13	2
Total derivative liabilities	$ 5	$ 3

XML

Derivative Instruments and Hedging Activities (Significant Unobservable Inputs) (Details) - Level 3	12 Months Ended
	Dec. 31, 2021 USD ($)
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	$ 1,401,000,000
Liabilities, Fair Value Disclosure	1,231,000,000
Forward Contracts - Power [Member] | Forward Contracts - Power [Member] | Forward Price [Member] | Maximum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	140
Forward Contracts - Power [Member] | Forward Contracts - Power [Member] | Forward Price [Member] | Minimum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	(5)
Forward Contracts - Power [Member] | Forward Contracts - Power [Member] | Forward Price [Member] | Weighted Average [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	37
Forward Contracts - Power [Member] | Derivative Financial Instruments, Assets [Member] | Forward Contracts - Power [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	433,000,000
Forward contracts - Gas [Member] | Forward contracts - Gas [Member] | Forward Price [Member] | Maximum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	15
Forward contracts - Gas [Member] | Forward contracts - Gas [Member] | Forward Price [Member] | Minimum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	2
Forward contracts - Gas [Member] | Forward contracts - Gas [Member] | Forward Price [Member] | Weighted Average [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	3
Forward contracts - Gas [Member] | Derivative Financial Instruments, Assets [Member] | Forward contracts - Gas [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	$ 191,000,000
Option Contracts, Power [Member] | Option Contracts, Power [Member] | Implied Correlations [Member] | Maximum [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	86.00%
Option Contracts, Power [Member] | Option Contracts, Power [Member] | Implied Correlations [Member] | Minimum [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	32.00%
Option Contracts, Power [Member] | Option Contracts, Power [Member] | Implied Correlations [Member] | Weighted Average [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	52.00%
Option Contracts, Power [Member] | Option Contracts, Power [Member] | Implied Volatilities [Member] | Maximum [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	368.00%
Option Contracts, Power [Member] | Option Contracts, Power [Member] | Implied Volatilities [Member] | Minimum [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	8.00%
Option Contracts, Power [Member] | Option Contracts, Power [Member] | Implied Volatilities [Member] | Weighted Average [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	81.00%
Option Contracts, Power [Member] | Derivative Financial Instruments, Assets [Member] | Option Contracts, Power [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	$ 52,000,000
Option Contracts, Primarily Gas [Member] | Options - primarily gas [Member] | Implied Correlations [Member] | Maximum [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	86.00%
Option Contracts, Primarily Gas [Member] | Options - primarily gas [Member] | Implied Correlations [Member] | Minimum [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	32.00%
Option Contracts, Primarily Gas [Member] | Options - primarily gas [Member] | Implied Correlations [Member] | Weighted Average [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	52.00%
Option Contracts, Primarily Gas [Member] | Options - primarily gas [Member] | Implied Volatilities [Member] | Maximum [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	295.00%
Option Contracts, Primarily Gas [Member] | Options - primarily gas [Member] | Implied Volatilities [Member] | Minimum [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	17.00%
Option Contracts, Primarily Gas [Member] | Options - primarily gas [Member] | Implied Volatilities [Member] | Weighted Average [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	36.00%
Option Contracts, Primarily Gas [Member] | Derivative Financial Instruments, Assets [Member] | Options - primarily gas [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	$ 356,000,000
Full Requirements and Unit Contingent Contracts [Member] | Full Requirements and Unit Contingent Contracts [Member] | Forward Price [Member] | Maximum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	308
Full Requirements and Unit Contingent Contracts [Member] | Full Requirements and Unit Contingent Contracts [Member] | Forward Price [Member] | Minimum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	2
Full Requirements and Unit Contingent Contracts [Member] | Full Requirements and Unit Contingent Contracts [Member] | Forward Price [Member] | Weighted Average [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	$ 64
Full Requirements and Unit Contingent Contracts [Member] | Full Requirements and Unit Contingent Contracts [Member] | Customer Migration Rate [Member] | Maximum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	19.00%
Full Requirements and Unit Contingent Contracts [Member] | Full Requirements and Unit Contingent Contracts [Member] | Customer Migration Rate [Member] | Minimum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	0.00%
Full Requirements and Unit Contingent Contracts [Member] | Full Requirements and Unit Contingent Contracts [Member] | Customer Migration Rate [Member] | Weighted Average [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Expected Rates	2.00%
Full Requirements and Unit Contingent Contracts [Member] | Derivative Financial Instruments, Assets [Member] | Full Requirements and Unit Contingent Contracts [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	$ 200,000,000
Forward contracts - Other | Derivative Financial Instruments, Assets [Member] | Forward contracts - Other
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	140,000,000
Forward contracts - Other | Derivative Financial Instruments, Assets [Member] | Forward contracts - Congestion | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	29,000,000
Forward contracts - Congestion | Forward contracts - Congestion | Forward Price [Member] | Maximum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	45
Forward contracts - Congestion | Forward contracts - Congestion | Forward Price [Member] | Minimum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	(10)
Forward contracts - Congestion | Forward contracts - Congestion | Forward Price [Member] | Weighted Average [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	0
Derivative Financial Instruments, Liabilities [Member] | Forward Contracts - Power [Member] | Forward Contracts - Power [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Liabilities, Fair Value Disclosure	204,000,000
Derivative Financial Instruments, Liabilities [Member] | Forward contracts - Gas [Member] | Forward contracts - Gas [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Liabilities, Fair Value Disclosure	31,000,000
Derivative Financial Instruments, Liabilities [Member] | Option Contracts, Power [Member] | Option Contracts, Power [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Liabilities, Fair Value Disclosure	(1,000,000)
Derivative Financial Instruments, Liabilities [Member] | Option Contracts, Primarily Gas [Member] | Options - primarily gas [Member] | Options Models, Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Liabilities, Fair Value Disclosure	347,000,000
Derivative Financial Instruments, Liabilities [Member] | Full Requirements and Unit Contingent Contracts [Member] | Full Requirements and Unit Contingent Contracts [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Liabilities, Fair Value Disclosure	566,000,000
Derivative Financial Instruments, Liabilities [Member] | Forward contracts - Other | Forward contracts - Other
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Liabilities, Fair Value Disclosure	76,000,000
Derivative Financial Instruments, Liabilities [Member] | Forward contracts - Other | Forward contracts - Congestion | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Liabilities, Fair Value Disclosure	$ 8,000,000

XML

Derivative Instruments and Hedging Activities (Reconciliation of Changes in the Fair Value) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative Financial Instruments, Net [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year	$ 1,374	$ 1,207	$ 647
Realized and unrealized gains (losses):
Included in earnings	(1,488)	547	923
Included in other comprehensive income (loss)	0	1	5
Included in regulatory assets and liabilities	8	2	1
Purchases	243	191	141
Sales	0	114	0
Settlements	259	(562)	(356)
Issuances	(196)	(123)	(87)
Transfers in	2	18	(5)
Transfers out	(32)	(21)	(62)
Fair value of net derivatives based on significant unobservable inputs at December 31	170	1,374	1,207
Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date	(924)	317	611
Realized and unrealized gains (losses) reflected in operating revenues	(1,488)	569	956
Unrealized gains (losses) reflected in operating revenues, for derivatives still held at the reporting date	(924)	317	638
FPL [Member] | Derivative Financial Instruments, Net [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year	(1)	(8)	(36)
Realized and unrealized gains (losses):
Included in earnings	0	0	0
Included in other comprehensive income (loss)	0	0	0
Included in regulatory assets and liabilities	8	2	1
Purchases	0	0	0
Sales	0	0	0
Settlements	1	6	25
Issuances	0	0	0
Transfers in	0	(1)	0
Transfers out	0	0	2
Fair value of net derivatives based on significant unobservable inputs at December 31	8	(1)	(8)
Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date	0	$ 0	$ 0
Level 3
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Liabilities, Fair Value Disclosure	$ 1,231

XML

Derivative Instruments (Income Statement Disclosure) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) on disposal of businesses/assets – net	$ 77	$ 353	$ 406
Not Designated as Hedging Instrument [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	(2,545)	(99)	20
Not Designated as Hedging Instrument [Member] | Commodity contracts | Gains (Losses) Included In Operating Revenues [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	(2,710)	352	762
Not Designated as Hedging Instrument [Member] | Foreign currency contracts | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	(89)	8	(7)
Not Designated as Hedging Instrument [Member] | Interest rate contracts | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	264	(421)	(699)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Not Designated as Hedging Instrument [Member] | Foreign currency contracts | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Interest Expense	(3)	(3)	(4)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Not Designated as Hedging Instrument [Member] | Interest rate contracts | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Interest Expense	(7)	(35)	(32)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Not Designated as Hedging Instrument [Member] | Interest rate contracts | Gains (Loss) On Disposal Of Businesses/Assets - Net [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) on disposal of businesses/assets – net		23
FPL [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) on commodity contracts, recorded as regulatory assets and or liabilities on the balance sheet due to regulatory treatment	$ 7	$ 6	$ 9

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Derivative Instruments (Net Notional Volumes and Additional Disclosures) (Details) bbl in Millions, MWh in Millions, MMBTU in Millions, $ in Billions	12 Months Ended
	Dec. 31, 2021 USD ($) MWh MMBTU bbl	Dec. 31, 2020 USD ($) MWh MMBTU bbl
Interest Rate Swap [Member]
Derivative [Line Items]
Derivative, Notional Amount | $	$ 11.2	$ 10.5
Foreign currency contracts
Derivative [Line Items]
Derivative, Notional Amount | $	$ 1.0	$ 1.0
Short [Member] | Commodity contract - Power [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount | MWh	103	90
Short [Member] | Commodity contract - Natural gas [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	1,290	607
Short [Member] | Commodity contract - Oil [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount, Volume | bbl	33	6
Short [Member] | FPL [Member] | Commodity contract - Oil [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount, Volume | bbl	0	0
Long [Member] | FPL [Member] | Commodity contract - Power [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount | MWh	0	0
Long [Member] | FPL [Member] | Commodity contract - Natural gas [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	91	87

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Derivative Instruments (Credit Risk Disclosures) (Details) - USD ($)	Dec. 31, 2021	Dec. 31, 2020
Derivative [Line Items]
Liability position of derivative	$ 4,100,000,000	$ 1,900,000,000
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Bbb Or Baa2	645,000,000	80,000,000
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Below Investment Grade	2,700,000,000	1,200,000,000
Additional Collateral Aggregate Fair Value Due To Other Financial Measures	1,040,000,000	880,000,000
Collateral Already Posted, Aggregate Fair Value	84,000,000	2,000,000
Letters Of Credit Already Posted Aggregate Fair Value	1,060,000,000	66,000,000
FPL [Member]
Derivative [Line Items]
Liability position of derivative	12,000,000	3,000,000
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Bbb Or Baa2	0	0
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Below Investment Grade	35,000,000	75,000,000
Additional Collateral Aggregate Fair Value Due To Other Financial Measures	145,000,000	75,000,000
Collateral Already Posted, Aggregate Fair Value	0	0
Letters Of Credit Already Posted Aggregate Fair Value	$ 0	$ 0

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Non-Derivative Fair Value Measurements (Assets and Liabilities Measured on a Recurring Basis) (Details) - Fair Value, Recurring [Member] - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	$ 176	$ 742
Special use funds [Abstract]
Equity securities	5,511	4,726
U.S. Government and municipal bonds	845	717
Corporate debt securities	962	871
Mortgage-backed securities	431	422
Other debt securities	267	124
Other Investments [Abstract]
Equity securities	72	62
Debt securities	285	218
Level 1
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	176	742
Special use funds [Abstract]
Equity securities	2,538	2,237
U.S. Government and municipal bonds	770	590
Corporate debt securities	7	1
Mortgage-backed securities	0	0
Other debt securities	2	0
Other Investments [Abstract]
Equity securities	70	62
Debt securities	111	91
Level 1 | Current other assets
Assets [Abstract]
Restricted cash	56	111
Level 1 | Other Noncurrent Assets [Member]
Assets [Abstract]
Restricted cash		42
Level 2
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	0	0
Special use funds [Abstract]
Equity securities	2,973	2,489
U.S. Government and municipal bonds	75	127
Corporate debt securities	955	870
Mortgage-backed securities	431	422
Other debt securities	265	124
Other Investments [Abstract]
Equity securities	2	0
Debt securities	162	127
Level 3
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	0	0
Special use funds [Abstract]
Equity securities	0	0
U.S. Government and municipal bonds	0	0
Corporate debt securities	0	0
Mortgage-backed securities	0	0
Other debt securities	0	0
Other Investments [Abstract]
Equity securities	0	0
Debt securities	12	0
FPL [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	58	137
Special use funds [Abstract]
Equity securities	3,552	3,012
U.S. Government and municipal bonds	668	536
Corporate debt securities	726	627
Mortgage-backed securities	313	335
Other debt securities	227	119
Other Investments [Abstract]
Equity securities	13	12
FPL [Member] | Level 1
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	58	137
Special use funds [Abstract]
Equity securities	862	752
U.S. Government and municipal bonds	624	449
Corporate debt securities	6	0
Mortgage-backed securities	0	0
Other debt securities	2	0
Other Investments [Abstract]
Equity securities	13	12
FPL [Member] | Level 1 | Current other assets
Assets [Abstract]
Restricted cash	53	91
FPL [Member] | Level 1 | Other Noncurrent Assets [Member]
Assets [Abstract]
Restricted cash		42
FPL [Member] | Level 2
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	0	0
Special use funds [Abstract]
Equity securities	2,690	2,260
U.S. Government and municipal bonds	44	87
Corporate debt securities	720	627
Mortgage-backed securities	313	335
Other debt securities	225	119
Other Investments [Abstract]
Equity securities	0	0
FPL [Member] | Level 3
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	0	0
Special use funds [Abstract]
Equity securities	0	0
U.S. Government and municipal bonds	0	0
Corporate debt securities	0	0
Mortgage-backed securities	0	0
Other debt securities	0	0
Other Investments [Abstract]
Equity securities	$ 0	$ 0

XML

Non-Derivative Fair Value Measurements (Nonrecurring Fair Value Measurements) (Details) - USD ($) $ in Millions	2 Months Ended	12 Months Ended
	Feb. 17, 2022	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets, carrying amount		$ 91,803	$ 82,010	$ 99,348
Impairment of long-lived assets			72
Impairment of long-lived assets, after tax			$ 54
NEER [Member] | Mountain Valley Pipeline [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets, carrying amount		1,900
Fair value of long-lived assets		400
Impairment of long-lived assets		1,500
Impairment of long-lived assets, after tax		$ 1,200
NEER [Member] | Mountain Valley Pipeline [Member] | Subsequent Event
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of long-lived assets	$ 800
Impairment of long-lived assets, after tax	600
Equity method investment write-off, carrying amount	600
Equity method investment, liability	$ 200

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Non-Derivative Fair Value Measurements - Contingent Consideration (Details) - GridLiance [Member] - USD ($) $ in Millions	Dec. 31, 2021	Mar. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration, liability		$ 264
NEER [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration, liability	$ 261

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Non-Derivative Fair Value Measurements (Fair Value of Instruments Recorded at Other than Fair Value) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	$ 906	$ 919
Other investments	102	29
Long-term debt, including current portion	52,745	46,082
Estimated Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	907	920
Other investments	102	29
Long-term debt, including current portion	57,290	51,525
FPL [Member] | Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	672	718
Long-term debt, including current portion	18,510	17,236
FPL [Member] | Estimated Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	672	719
Long-term debt, including current portion	$ 21,379	$ 21,178

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Non-Derivative Fair Value Measurements (Gains and Losses) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Schedule of Available-for-sale Securities[Line Items]
Decommissioning Fund Investments, Fair Value	$ 8,846	$ 7,703
Special Use Funds Storm Fund Assets	76	76
Debt securities, amortized cost	$ 2,438	2,009
Special Use Funds Nuclear Decommissioning Funds Weighted Average Maturity	8 years
Special Use Funds Storm Fund Weighted Average Maturity	1 year
Debt Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
Realized gains	$ 78	110	$ 68
Realized losses	73	70	48
Proceeds from sale and maturity of Available-for-sale Securities	1,831	2,541	3,005
Available for sale securities: Special Use Funds - Debt Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
Unrealized gains	76	134
Unrealized losses	19	9
Fair Value	1,100	201
FPL [Member]
Schedule of Available-for-sale Securities[Line Items]
Decommissioning Fund Investments, Fair Value	6,082	5,271
Special Use Funds Storm Fund Assets	76	76
Debt securities, amortized cost	$ 1,877	1,521
Special Use Funds Nuclear Decommissioning Funds Weighted Average Maturity	8 years
Special Use Funds Storm Fund Weighted Average Maturity	1 year
FPL [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
Realized gains	$ 59	83	44
Realized losses	57	56	29
Proceeds from sale and maturity of Available-for-sale Securities	1,330	2,162	2,539
FPL [Member] | Available for sale securities: Special Use Funds - Debt Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
Unrealized gains	63	104
Unrealized losses	15	9
Fair Value	857	150
Equity Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
marketable securities, unrealized gain (loss) recognized during the period on securities still held	981	627	780
Equity Securities [Member] | FPL [Member]
Schedule of Available-for-sale Securities[Line Items]
marketable securities, unrealized gain (loss) recognized during the period on securities still held	$ 652	$ 444	$ 510

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Income Taxes - Components of Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020		Dec. 31, 2019
Federal:
Current	$ (26)	$ 105		$ 167
Deferred	311	(148)		115
Total federal	285	(43)		282
State:
Current	(62)	18		23
Deferred	125	69		143
Total state	63	87		166
Total income taxes	348	44		448
FPL [Member]
Federal:
Current	85	16		390
Deferred	545	474		(41)
Total federal	630	490		349
State:
Current	1	32		50
Deferred	207	156		85
Total state	208	188		135
Total income taxes	$ 838	$ 678	[1]	$ 484	[1]

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

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Income Taxes - Reconciliation of Effective Income Tax Rate (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Loss Carryforwards [Line Items]
Statutory federal income tax rate	21.00%	21.00%	21.00%
Increases (reductions) resulting from:
State income taxes – net of federal income tax benefit(a)	1.60%	2.80%	3.40%
Taxes attributable to noncontrolling interests	5.00%	4.80%	2.10%
PTCs and ITCs – NEER	(10.30%)	(11.80%)	(7.20%)
Amortization of deferred regulatory credit(b)	(4.40%)	(7.20%)	(6.20%)
Foreign operations(c)	0.20%	(2.40%)	0.00%
Other – net	(2.10%)	(5.40%)	(1.40%)
Effective income tax rate (in hundredths)	11.00%	1.80%	11.70%
State [Member]
Increases (reductions) resulting from:
Deferred Income Taxes and Tax Credits		$ 48
FPL [Member]
Operating Loss Carryforwards [Line Items]
Statutory federal income tax rate	21.00%	21.00%	21.00%
Increases (reductions) resulting from:
State income taxes – net of federal income tax benefit(a)	4.10%	4.20%	3.50%
Taxes attributable to noncontrolling interests	0.00%	0.00%	0.00%
PTCs and ITCs – NEER	0.00%	0.00%	0.00%
Amortization of deferred regulatory credit(b)	(3.50%)	(4.90%)	(8.00%)
Foreign operations(c)	0.00%	0.00%	0.00%
Other – net	(0.90%)	(1.30%)	(0.40%)
Effective income tax rate (in hundredths)	20.70%	19.00%	16.10%
Amortization of deferred regulatory credit		$ 83
Amortization Of Excess Deferred Income Taxes		$ 870

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Income Taxes - Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Deferred tax liabilities:
Property-related	$ 10,018	$ 10,065
Pension	564	437
Investments in partnerships and joint ventures	2,783	2,238
Other	2,092	1,730
Total deferred tax liabilities	15,457	14,470
Deferred tax assets and valuation allowance:
Decommissioning reserves	296	290
Net operating loss carryforwards	330	299
Tax credit carryforwards	4,646	3,859
ARO and accrued asset removal costs	199	347
Regulatory liabilities	1,421	1,380
Other	733	755
Valuation allowance	(282)	(289)
Net deferred tax assets	7,343	6,641
Net deferred income taxes	8,114	7,829
Deferred tax assets and liabilities included in the consolidated balance sheets [Abstract]
Noncurrent other assets	196	191
Deferred income taxes – noncurrent liabilities	(8,310)	(8,020)
Net deferred income taxes	(8,114)	(7,829)
FPL [Member]
Deferred tax liabilities:
Property-related	7,831	7,548
Pension	425	394
Investments in partnerships and joint ventures	3	3
Other	1,232	862
Total deferred tax liabilities	9,491	8,807
Deferred tax assets and valuation allowance:
Decommissioning reserves	296	290
Net operating loss carryforwards	2	3
Tax credit carryforwards	182	4
ARO and accrued asset removal costs	126	272
Regulatory liabilities	1,397	1,356
Other	351	363
Valuation allowance	0	0
Net deferred tax assets	2,354	2,288
Net deferred income taxes	7,137	6,519
Deferred tax assets and liabilities included in the consolidated balance sheets [Abstract]
Noncurrent other assets	0	0
Deferred income taxes – noncurrent liabilities	(7,137)	(6,519)	[1]
Net deferred income taxes	$ (7,137)	$ (6,519)

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

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Income Taxes - Tax Carryforwards and Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	$ 330	$ 299
Tax credit carryforwards	4,646	$ 3,859
Federal [Member]
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	51
Tax credit carryforwards	4,296
Net operating loss carryforwards with indefinite expiration period	49
State [Member]
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	264
Tax credit carryforwards	345
Tax credit carryforward with indefinite expiration period	191
Foreign [Member]
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	15
Tax credit carryforwards	$ 5

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Acquisitions (Details) $ in Millions	Mar. 31, 2021 USD ($) state utlity mi	Jul. 16, 2019 USD ($) mi	Jan. 01, 2019 USD ($) customer county mi MW	Dec. 31, 2021 USD ($) county	Jan. 01, 2021 USD ($)	Dec. 31, 2020 USD ($)
Business Acquisition [Line Items]
Number of counties In which entity operates | county				8
Goodwill				$ 4,844		$ 4,254
Gulf Power [Member]
Business Acquisition [Line Items]
Cash consideration			$ 4,440
Debt assumed			1,300		$ 1,800
Assets assumed			5,200		6,700
Property, plant, and equipment			4,000		4,900
Regulatory assets			494		1,200
Assumed liabilities			3,400		3,900
Regulatory liabilities			635		566
Deferred income taxes			$ 562		$ 729
Goodwill				2,700
Trans Bay Cable, LLC [Member]
Business Acquisition [Line Items]
Cash consideration		$ 670
Debt assumed		422
Assets assumed		703
Assumed liabilities		$ 643
Goodwill				610
Goodwill, expected tax deductible amount				572
GridLiance [Member]
Business Acquisition [Line Items]
Assets assumed	$ 384
Assumed liabilities	210
Goodwill				592
Goodwill, expected tax deductible amount				586
Cash consideration	502
Business combination, assumption of debt	175
Contingent consideration, liability	$ 264
Gulf Power [Member] | Gulf Power [Member]
Business Acquisition [Line Items]
Number of customers served | customer			470,000
Number of counties In which entity operates | county			8
Length of power lines (mi) | mi			9,500
Natural Gas And Or Oil Electric Generating Facility Capacity | MW			2,300
FPL [Member]
Business Acquisition [Line Items]
Goodwill				2,989		$ 2,989	[1]
FPL [Member] | Gulf Power [Member]
Business Acquisition [Line Items]
Goodwill				$ 2,700
Trans Bay Cable, LLC [Member] | Trans Bay Cable, LLC [Member]
Business Acquisition [Line Items]
Length of power lines (mi) | mi		53
GridLiance Holdco, LP and GridLiance GP, LLC | GridLiance [Member]
Business Acquisition [Line Items]
Length of power lines (mi) | mi	700
Number Of FERC-Regulated Transmission Utilities | utlity	3
Number of States in which Entity Operates | state	6
GridLiance Holdco, LP and GridLiance GP, LLC | GridLiance [Member] | Midwest And Nevada [Member]
Business Acquisition [Line Items]
Number of States in which Entity Operates | state	5

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

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Property, Plant and Equipment - Schedule Of Property Plant and Equipment (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020		Dec. 31, 2019
Jointly Owned Utility Plant Interests [Line Items]
Electric plant in service and other property	$ 112,500	$ 105,860
Nuclear fuel	1,606	1,604
Construction work in progress	14,141	10,639
Property, plant and equipment, gross	128,247	118,103
Accumulated depreciation and amortization	(28,899)	(26,300)
Property, plant and equipment - net	99,348	91,803		$ 82,010
FPL [Member]
Jointly Owned Utility Plant Interests [Line Items]
Electric plant in service and other property	67,771	62,963
Nuclear fuel	1,170	1,143
Construction work in progress	6,326	5,361
Property, plant and equipment, gross	75,267	69,467
Accumulated depreciation and amortization	(17,040)	(15,588)
Electric utility plant and other property – net	$ 58,227	$ 53,879	[1]	$ 49,837

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

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Property, Plant and Equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Jointly Owned Utility Plant Interests [Line Items]
Property, plant and equipment – net	$ 99,348	$ 91,803	$ 82,010
FPL [Member]
Jointly Owned Utility Plant Interests [Line Items]
Amount of reserve (reversal) amortization recognized	$ 429	$ (1)	$ (357)
AFUDC capitalization rate (in hundredths)	6.22%	6.22%	6.22%
AFUDC capitalized	$ 124	$ 79	$ 80
Gulf Power [Member]
Jointly Owned Utility Plant Interests [Line Items]
AFUDC capitalization rate (in hundredths)	5.73%	5.73%	5.73%
AFUDC capitalized	$ 53	$ 38	$ 6
FPL [Member]
Jointly Owned Utility Plant Interests [Line Items]
Percentage of electric generating assets to gross investment in electric utility plant in service (in hundredths)	46.00%	47.00%
Percentage of electric transmission assets to gross investment in electric utility plant in service (in hundredths)	13.00%	12.00%
Percentage of electric distribution assets to gross investment in electric utility plant in service (in hundredths)	35.00%	35.00%
Percentage of general facilities assets to gross investment in electric utility plant in service (in hundredths)	6.00%	6.00%
FPL's composite depreciation rate for electric plant in service (in hundredths)	3.80%	3.80%	3.90%
FPL [Member] | St. Lucie Unit No. 2
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	85.00%
Gross Investment	$ 2,284
Accumulated Depreciation	1,044
Construction Work in Progress	$ 90
FPL [Member] | Daniel Units Nos. 1 and 2
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
Gross Investment	$ 759
Accumulated Depreciation	274
Construction Work in Progress	$ 16
FPL [Member] | Scherer Unit No. 3
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	25.00%
Gross Investment	$ 449
Accumulated Depreciation	204
Construction Work in Progress	3
NEER [Member]
Jointly Owned Utility Plant Interests [Line Items]
Net Book Value Of Assets Serving As Collateral	13,500
Interest capitalized on construction projects of NextEra Energy Resources	$ 139	$ 168	$ 135
NEER [Member] | Wind plants [Member]
Jointly Owned Utility Plant Interests [Line Items]
Percentage of gross depreciable assets by plant type	53.00%	55.00%
NEER [Member] | Wind plants [Member] | Minimum [Member]
Jointly Owned Utility Plant Interests [Line Items]
Property, plant and equipment, estimated useful lives (in years)	30 years
NEER [Member] | Wind plants [Member] | Maximum [Member]
Jointly Owned Utility Plant Interests [Line Items]
Property, plant and equipment, estimated useful lives (in years)	35 years
NEER [Member] | Solar plants [Member]
Jointly Owned Utility Plant Interests [Line Items]
Percentage of gross depreciable assets by plant type	14.00%	13.00%
NEER [Member] | Solar plants [Member] | Minimum [Member]
Jointly Owned Utility Plant Interests [Line Items]
Property, plant and equipment, estimated useful lives (in years)	30 years
NEER [Member] | Solar plants [Member] | Maximum [Member]
Jointly Owned Utility Plant Interests [Line Items]
Property, plant and equipment, estimated useful lives (in years)	35 years
NEER [Member] | Oil and Gas Properties [Member]
Jointly Owned Utility Plant Interests [Line Items]
Percentage of gross depreciable assets by plant type	14.00%	14.00%
NEER [Member] | Nuclear Plant [Member]
Jointly Owned Utility Plant Interests [Line Items]
Percentage of gross depreciable assets by plant type	8.00%	8.00%
NEER [Member] | Nuclear Plant [Member] | Minimum [Member]
Jointly Owned Utility Plant Interests [Line Items]
Property, plant and equipment, estimated useful lives (in years)	23 years
NEER [Member] | Nuclear Plant [Member] | Maximum [Member]
Jointly Owned Utility Plant Interests [Line Items]
Property, plant and equipment, estimated useful lives (in years)	47 years
NEER [Member] | Seabrook
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	88.23%
Gross Investment	$ 1,330
Accumulated Depreciation	453
Construction Work in Progress	$ 58
NEER [Member] | Wyman Station Unit No. 4
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	91.19%
Gross Investment	$ 30
Accumulated Depreciation	11
Construction Work in Progress	$ 0
NEER [Member] | Stanton
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	65.00%
Gross Investment	$ 139
Accumulated Depreciation	19
Construction Work in Progress	$ 0
NEER [Member] | Transmission substation assets located in Seabrook, New Hampshire
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	88.23%
Gross Investment	$ 114
Accumulated Depreciation	8
Construction Work in Progress	$ 22

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Equity Method Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Equity method investment, financial statement, reported amounts [Abstract]
NextEra Energy Resources' ownership interest, low range (in hundredths)	32.00%
NextEra Energy Resources' ownership interest, high range (in hundredths)	55.00%
Equity method investment, summarized financial information [Abstract]
Operating revenue	$ 17,069	$ 17,997	$ 19,204
Operating income	2,913	5,116	5,353
Net income	(746)	(550)	(381)
Total assets	140,912	127,684	117,691
Total liabilities	95,243	82,755
Investment in equity method investees	6,159	5,728	7,453
Interest and Fee Income, Other Loans	148	120	$ 101
Due from Related Parties, Current	113	68
Due from Related Parties, Noncurrent	40	32
Guarantor Obligations, Current Carrying Value	484
Equity Method Investment, Nonconsolidated Investee, Other
Equity method investment, summarized financial information [Abstract]
Operating revenue	1,469	1,359
Operating income	559	538
Net income	739	516
Total assets	29,537	22,717
Total liabilities	9,501	6,612
Partners'/members' equity	20,036	16,105
NEER [Member]
Equity method investment, summarized financial information [Abstract]
NEE's share of underlying equity in the principal entities	4,352	3,927
Difference between investment carrying amount and underlying equity in net assets	1,133	1,312
Investment in equity method investees	5,485	5,239
NEP OpCo [Member]
Equity method investment, summarized financial information [Abstract]
Difference between investment carrying amount and underlying equity in net assets	$ 2,600	$ 2,800
Difference related to goodwill	75.00%	70.00%
NEP [Member]
Equity method investment, summarized financial information [Abstract]
Due to Related Parties	$ 57	$ 10
Guarantor Obligations, Current Carrying Value	3,778
Guarantees, Fair Value Disclosure	$ 41
Mountain Valley Pipeline [Member]
Equity method investment, summarized financial information [Abstract]
Difference between investment carrying amount and underlying equity in net assets		$ 1,500
Minimum [Member] | NEP OpCo [Member]
Equity method investment, summarized financial information [Abstract]
Amortization period	17 years
Maximum [Member] | NEP OpCo [Member]
Equity method investment, summarized financial information [Abstract]
Amortization period	25 years

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Variable Interest Entities (VIEs) (Details) $ in Millions	3 Months Ended	6 Months Ended	12 Months Ended
	Dec. 31, 2021 USD ($) variable_interest_entity MW	Jun. 30, 2022 MW	Dec. 31, 2021 USD ($) variable_interest_entity mi MW	Dec. 31, 2019 USD ($) MW	Dec. 31, 2020 USD ($) variable_interest_entity
Variable Interest Entity [Line Items]
Carrying amount of assets, consolidated variable interest entity	$ 140,912		$ 140,912	$ 117,691	$ 127,684
Carrying amount of liabilities, consolidated variable interest entity	95,243		95,243		82,755
Investment in equity method investees	6,159		6,159	7,453	5,728
Variable Interest Entity Other [Member]
Variable Interest Entity [Line Items]
Investments in special purpose entities	4,559		4,559		3,704
Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Carrying amount of assets, consolidated variable interest entity	614		614		423
Carrying amount of liabilities, consolidated variable interest entity	64		$ 64		68
Variable Interest Entity, Consolidated, Income Allocation, Percentage			50.00%
Electricity Transmission Line | mi			280
FPL [Member]
Variable Interest Entity [Line Items]
Carrying amount of assets, consolidated variable interest entity	78,067		$ 78,067	$ 65,690	71,001	[1]
Carrying amount of liabilities, consolidated variable interest entity	44,473		44,473		41,773	[1]
FPL [Member] | Variable Interest Entity Other [Member]
Variable Interest Entity [Line Items]
Investments in special purpose entities	$ 3,799		$ 3,799		$ 3,124
Indirect Subsidiary of NextEra Energy Resources [Member] | Photovoltaic Solar Facility [Member]
Variable Interest Entity [Line Items]
Total Number Of Consolidated Variable Interest Entities | variable_interest_entity	8		8		3
Carrying amount of assets, consolidated variable interest entity	$ 1,851		$ 1,851		$ 751
Carrying amount of liabilities, consolidated variable interest entity	1,258		$ 1,258		607
Solar generating facility capability | MW			772
Indirect Subsidiary of NextEra Energy Resources [Member] | Photovoltaic Solar Facility [Member] | Minimum [Member]
Variable Interest Entity [Line Items]
Ownership percentage (in hundredths)			50.00%
Indirect Subsidiary of NextEra Energy Resources [Member] | Photovoltaic Solar Facility [Member] | Maximum [Member]
Variable Interest Entity [Line Items]
Ownership percentage (in hundredths)			67.00%
NextEra Energy Resources Consolidated VIE [Member] | 10% direct ownership in wind and solar facilities
Variable Interest Entity [Line Items]
Carrying amount of assets, consolidated variable interest entity	1,518		$ 1,518		1,572
Carrying amount of liabilities, consolidated variable interest entity	$ 79		79		393
Ownership percentage (in hundredths)	10.00%
Wind electric generating facility capability (in megawatts) | MW	400
Solar generating facility capability | MW	599
NEER [Member]
Variable Interest Entity [Line Items]
Wind electric generating facility capability (in megawatts) | MW				220
Investment in equity method investees	$ 5,485		$ 5,485		5,239
NEER [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Wind electric generating facility capability (in megawatts) | MW			11,226
Solar generating facility capability | MW			1,894
NEER [Member] | Variable Interest Entities Wind and Solar Primary Beneficiary [Member] [Member]
Variable Interest Entity [Line Items]
Carrying amount of assets, consolidated variable interest entity	17,419		$ 17,419		16,180
Carrying amount of liabilities, consolidated variable interest entity	1,480		$ 1,480		1,741
Wind electric generating facility capability (in megawatts) | MW			10,626
NEER [Member] | Variable Interest Entities Wind and Solar Primary Beneficiary [Member] [Member] | Forecast [Member]
Variable Interest Entity [Line Items]
Wind electric generating facility capability (in megawatts) | MW		200
Other Investments [Member] | Subsidiaries of NEE [Member]
Variable Interest Entity [Line Items]
Investment in equity method investees	4,214		$ 4,214		$ 3,932
Commitments To Increase (Decrease) In Equity Method Investments	$ 110		$ 110

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

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Leases (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($) agreement	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Lessee, Lease, Description [Line Items]
Number Of Land Use Agreements | agreement	3
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other	Other	Other
Operating Lease, Liability, Statement of Financial Position [Extensible List]	Other Liabilities	Other Liabilities	Other Liabilities
ROU assets, operating leases	$ 547	$ 535
Lease liabilities, operating leases	$ 555	$ 541
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other	Other	Other
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Liabilities	Other Liabilities	Other Liabilities
ROU assets, finance leases	$ 205	$ 128
Lease liabilities, finance leases	$ 200	$ 124
Weighted average incremental borrowing rate at the lease inception, operating leases	3.57%	3.81%
Weighted average incremental borrowing rate at the lease inception, finance leases	3.52%	3.50%
Weighted-average remaining lease term, operating leases	39 years	33 years
Weighted-average remaining lease term, finance leases	31 years	25 years
Expected lease payments over the remaining terms of the leases	$ 1,400
Operating Lease, Expense	92	$ 95	$ 91
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	92	121	450
Net investment in sales-type leases	42	$ 47
Operating and Sales-type Leases, Lease Receivable, Payments to be Received	$ 843
FPL [Member]
Lessee, Lease, Description [Line Items]
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability			$ 262
Maximum [Member]
Lessee, Lease, Description [Line Items]
Lease extension term, operating lease	20 years

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Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Asset retirement obligation, roll forward analysis [Roll Forward]
Beginning balance	$ 3,166	$ 3,506
Liabilities incurred	79	138
Accretion expense	141	169
Liabilities settled	(88)	(53)
Revision in estimated cash flows – net	(119)	(594)
Ending balance	3,179	3,166
Current portion	97	109
Liabilities settled related to project sales and other disposals	35
Restricted funds included in special use funds [Abstract]
Restricted funds	$ 8,846	7,703
St. Lucie Units Number One
Asset retirement obligation, roll forward analysis [Roll Forward]
License renewal period	20 years
St. Lucie Units Number Two
Asset retirement obligation, roll forward analysis [Roll Forward]
License renewal period	20 years
FPL [Member]
Asset retirement obligation, roll forward analysis [Roll Forward]
Beginning balance	$ 1,936	2,410
Liabilities incurred	7	0
Accretion expense	78	103
Liabilities settled	(15)	(32)
Revision in estimated cash flows – net	101	(545)
Ending balance	2,107	1,936
Current portion	58	65
Restricted funds included in special use funds [Abstract]
Restricted funds	$ 6,082	$ 5,271
FPL [Member] | St. Lucie Units Number One
Asset retirement obligation, roll forward analysis [Roll Forward]
License renewal period	20 years
FPL [Member] | St. Lucie Units Number Two
Asset retirement obligation, roll forward analysis [Roll Forward]
License renewal period	20 years

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Employee Retirement Benefits - Plan Assets, Benefit Obligations and Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Other Postretirement Benefits Plan [Member]
Change in pension benefit obligation:
Service cost	$ 2	$ 1	$ 1
Interest cost	4	8	9
Special termination benefits	0	0	0
Funded status:
Prepaid (accrued) benefit cost	(300)	(323)
Pension Benefits [Member]
Change in pension plan assets:
Plan assets, beginning balance	5,314	4,800
Actual return on plan assets	627	723
Benefit payments	(253)	(209)
Plan assets, ending balance	5,688	5,314	4,800
Change in pension benefit obligation:
Obligation, beginning balance	3,607	3,363
Service cost	90	85	80
Interest cost	64	92	114
Special termination benefits	0	16	19
Plan amendments	0	1
Actuarial losses (gains) – net	(63)	259
Benefit payments	(253)	(209)
Obligation, ending balance	3,445	3,607	$ 3,363
Funded status:
Prepaid (accrued) benefit cost	2,243	1,707
Accumulated benefit obligation	3,352	3,521
FPL [Member] | Other Postretirement Benefits Plan [Member]
Funded status:
Prepaid (accrued) benefit cost	(139)	(156)
FPL [Member] | Pension Benefits [Member]
Funded status:
Prepaid (accrued) benefit cost	$ 1,657	$ 1,550

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Employee Retirement Benefits - Unrecognized Amounts (Details) - Pension Benefits [Member] - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Components of AOCI:
Unrecognized prior service benefit	$ 2	$ 2
Unrecognized losses	41	(60)
Total	43	(58)
Tax effects on components of AOCI [Abstract]
Tax expense (benefit) related to unrecognized prior service benefit (cost)	1	1
Tax expense (benefit) related to unrecognized gain (loss)	7	(24)
Unrecognized amounts included in regulatory assets (liabilities) [Abstract]
Unrecognized prior service benefit	(1)	(1)
Unrecognized losses (gains)	(80)	163
Total	$ (81)	$ 162

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Employee Retirement Benefits - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Target asset allocations [Abstract]
Defined contribution expense	$ 66	$ 64	$ 58
Pension Benefits [Member]
Weighted-average assumptions used to determine benefit obligations [Abstract]
Discount rate (in hundredths)	2.87%	2.53%
Salary increase (in hundredths)	4.90%	4.40%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Weighted-Average Interest Crediting Rate	3.79%	3.82%
Pension Benefits [Member] | Equity Securities [Member]
Target asset allocations [Abstract]
Equity investments, target allocation percentage (in hundredths)	45.00%
Pension Benefits [Member] | Debt Securities [Member]
Target asset allocations [Abstract]
Equity investments, target allocation percentage (in hundredths)	32.00%
Pension Benefits [Member] | Alternative Investments [Member]
Target asset allocations [Abstract]
Equity investments, target allocation percentage (in hundredths)	13.00%
Pension Benefits [Member] | Convertible Securities [Member]
Target asset allocations [Abstract]
Equity investments, target allocation percentage (in hundredths)	10.00%
FPL [Member]
Target asset allocations [Abstract]
Defined contribution expense	$ 42	$ 40	$ 40

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Employee Retirement Benefits - Fair Value of Pension Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Fair Value Measured at Net Asset Value Per Share
Fair value measurements of plan assets [Abstract]
Foreign investments	$ 220	$ 153
Equity Securities [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	927	881
Equity Securities [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	2,008	2,030
Equity Securities [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	1,977	2,017
Equity Securities [Member] | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	29	10
Equity Securities [Member] | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	2	3
Equity Commingled Vehicles [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	169	156
Equity Commingled Vehicles [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	889	668
Equity Commingled Vehicles [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Equity Commingled Vehicles [Member] | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	889	668
Equity Commingled Vehicles [Member] | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
U.S. Government And Municipal Bonds [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	137	177
U.S. Government And Municipal Bonds [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	131	169
U.S. Government And Municipal Bonds [Member] | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	6	8
U.S. Government And Municipal Bonds [Member] | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Corporate debt securities [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	109	93
Corporate debt securities [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	351	340
Corporate debt securities [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Corporate debt securities [Member] | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	351	340
Corporate debt securities [Member] | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Asset-backed securities [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	386	375
Asset-backed securities [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Asset-backed securities [Member] | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	386	375
Asset-backed securities [Member] | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Debt Security Commingled Vehicles [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	5
Debt Security Commingled Vehicles [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	219	201
Debt Security Commingled Vehicles [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Debt Security Commingled Vehicles [Member] | Level 2
Fair value measurements of plan assets [Abstract]
Fair value	219	201
Debt Security Commingled Vehicles [Member] | Level 3
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Convertible securities [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	41	5
Convertible securities [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	580	517
Convertible securities [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	91	64
Convertible securities [Member] | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	489	453
Convertible securities [Member] | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Investments measured at net asset value [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments		35
Total Investments
Fair value measurements of plan assets [Abstract]
Fair value	5,688	5,314
Total Investments | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	4,570	4,308
Total Investments | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	2,199	2,250
Total Investments | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	2,369	2,055
Total Investments | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	2	3
Total Investments | Fair Value Measured at Net Asset Value Per Share | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	$ 1,118	$ 1,006

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Employee Retirement Benefits - Expected Cash Flows (Details) - Pension Benefits [Member] $ in Millions	Dec. 31, 2021 USD ($)
Defined Benefit Plan Disclosure [Line Items]
2022	$ 204
2023	208
2024	209
2025	210
2026	214
2027 – 2031	$ 1,033

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Employee Retirement Benefits - Net Periodic Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Service cost	$ 90	$ 85	$ 80
Interest cost	64	92	114
Expected return on plan assets	(339)	(321)	(312)
Amortization of actuarial loss	24	18	0
Amortization of prior service benefit	(1)	(1)	(1)
Special termination benefits	0	16	19
Net periodic (income) cost	(162)	(111)	(100)
Other Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Service cost	2	1	1
Interest cost	4	8	9
Expected return on plan assets	0	0	0
Amortization of actuarial loss	5	3	0
Amortization of prior service benefit	(15)	(16)	(15)
Special termination benefits	0	0	0
Net periodic (income) cost	(4)	(4)	(5)
FPL [Member] | Pension Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Net periodic (income) cost	(108)	(84)	(61)
FPL [Member] | Other Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Net periodic (income) cost	$ (4)	$ (4)	$ (4)

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Employee Retirement Benefits - Net Periodic Income Cost Recognizedf for OCI (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Reclassification from accumulated other comprehensive income (loss) to net income	$ 5	$ 2	$ (3)
Tax effects on components of net periodic income (cost) recognized in OCI [Abstract]
Reclassification from accumulated other comprehensive income (loss) to net income, tax expense (benefit)	(1)	(1)	(1)
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net gains (losses)	95	42	(36)
Reclassification from accumulated other comprehensive income (loss) to net income	6	5	0
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax and Reclassification Adjustment, Attributable to Parent	101	47	(36)
Tax effects on components of net periodic income (cost) recognized in OCI [Abstract]
Net gains (losses)	29	13	$ (10)
Reclassification from accumulated other comprehensive income (loss) to net income, tax expense (benefit)	$ 2	$ 1

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Employee Retirement Benefits - Net Periodic Income Cost Regulatory Assets (Details) - Pension Benefits [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost Recognized In Regulatory Assets Liabilities	$ (1)	$ 1
Unrecognized gains	(226)	(89)
Amortization of prior service benefit	0	1
Amortization Of Unrecognized Losses Recognized In Regulatory Assets Liabilities	(16)	(12)
Total	$ (243)	$ (99)

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Employee Retirement Benefits - Assumptions Used for Periodic Income (Details) - Pension Benefits [Member]	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Discount rate	2.53%	3.22%	4.26%
Salary increase	4.40%	4.40%	4.40%
Expected long-term rate of return, net of management fees	7.35%	7.35%	7.35%
Weighted-average interest crediting rate	3.82%	3.83%	3.88%

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Debt (Schedule of Debt Instruments) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Less current maturities of long-term debt	$ 1,785	$ 4,138
Long-term debt, excluding current maturities	50,960	41,944
Repayment prior to maturity	1,785
FPL [Member]
Debt Instrument [Line Items]
Unamortized debt issuance costs and premium and discount	(191)	(182)
Total long-term debt	18,510	17,236
Less current maturities of long-term debt	536	354	[1]
Long-term debt, excluding current maturities	17,974	16,882	[1]
Repayment prior to maturity	536
FPL [Member] | First mortgage bonds - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 14,290	$ 13,090
Weighted-average interest rate	4.20%	4.32%
FPL [Member] | Pollution control, solid waste disposal and industrial development revenue bonds - primary variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 1,407	$ 1,407
Weighted-average interest rate	0.15%	0.17%
Variable rate tax exempt bonds	$ 1,375
FPL [Member] | Senior Unsecured Notes - Primarily Variable
Debt Instrument [Line Items]
Long-term debt, gross	$ 2,697	$ 2,621
Weighted-average interest rate	1.37%	1.55%
Floating rate notes that permit individual noteholders to require repayment prior to maturity	$ 882
FPL [Member] | Other long-term debt - variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 307	$ 300
Weighted-average interest rate	0.82%	0.70%
NEER [Member]
Debt Instrument [Line Items]
Unamortized debt issuance costs and premium and discount	$ (92)	$ (65)
Total long-term debt	7,419	4,647
Less current maturities of long-term debt	664	239
Long-term debt, excluding current maturities	6,755	4,408
NEER [Member] | Senior secured limited-recourse term loans - variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 3,100	$ 2,621
Weighted-average interest rate	1.74%	1.99%
NEER [Member] | Senior secured limited-recourse long-term loans - fixed
Debt Instrument [Line Items]
Long-term debt, gross	$ 2,475	$ 704
Weighted-average interest rate	3.30%	3.59%
NEER [Member] | Other Long-Term Debt - Primarily Variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 785	$ 450
Weighted-average interest rate	2.50%	2.72%
Capital Holdings [Member]
Debt Instrument [Line Items]
Unamortized debt issuance costs and premium and discount	$ (120)	$ (115)
Total long-term debt	26,816	24,199
Less current maturities of long-term debt	585	3,545
Long-term debt, excluding current maturities	26,231	20,654
Capital Holdings [Member] | Other long-term debt - variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 1,245	$ 600
Weighted-average interest rate	0.64%	0.70%
Capital Holdings [Member] | Other long-term debt - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 186	$ 221
Weighted-average interest rate	0.92%	0.92%
Capital Holdings [Member] | Debentures - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 10,990	$ 11,540
Weighted-average interest rate	2.21%	2.86%
Capital Holdings [Member] | Debentures variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 3,850	$ 1,225
Weighted-average interest rate	0.56%	0.80%
Capital Holdings [Member] | Debentures, related to NEE's equity units - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 6,000	$ 6,000
Weighted-average interest rate	1.46%	1.46%
Capital Holdings [Member] | Junior subordinated debentures - primarily fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 3,723	$ 3,693
Weighted-average interest rate	4.54%	4.78%
Capital Holdings [Member] | Japanese yen denominated term loans - variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 582	$ 650
Weighted-average interest rate	1.49%	1.49%
Capital Holdings [Member] | Australian dollar denominated long-term debt - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 360	$ 385
Weighted-average interest rate	2.20%	2.20%
NEET [Member] | Other long-term debt - fixed [Member] | NEER [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 1,151	$ 937
Weighted-average interest rate	2.69%	3.09%

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

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Debt (Minimum Annual Maturities) (Details) $ in Thousands	Dec. 31, 2021 USD ($)
Debt Instrument [Line Items]
Year One	$ 1,785,000
Year Two	8,394,000
Year Three	3,672,000
Year Four	6,536,000
Year Five	1,322,000
FPL [Member]
Debt Instrument [Line Items]
Year One	536,000
Year Two	1,548,000
Year Three	646,000
Year Four	1,700,000
Year Five	$ 200

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Debt (Narrative) (Details) - USD ($)	1 Months Ended			3 Months Ended	12 Months Ended
	Sep. 30, 2020	Feb. 29, 2020	Sep. 30, 2019	Sep. 30, 2019	Dec. 31, 2020	Jan. 31, 2022	Dec. 31, 2021	Aug. 31, 2019
Debt Instrument [Line Items]
Weighted-average interest rate of commercial paper and short-tem borrowings (in hundredths)					0.35%		0.39%
Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity							$ 12,100,000,000
Letter of Credit [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity							1,000,000
Revolving Credit Facility [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity							11,100,000,000
Revolving Credit Facility, Issuance of Letters of Credit [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity							$ 1,900,000,000
FPL [Member]
Debt Instrument [Line Items]
Weighted-average interest rate of commercial paper and short-tem borrowings (in hundredths)					0.28%		0.27%
FPL [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity							$ 4,600,000,000
FPL [Member] | Letter of Credit [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity							0
FPL [Member] | Revolving Credit Facility [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity							4,600,000,000
FPL [Member] | Revolving Credit Facility, Issuance of Letters of Credit [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity							$ 647,000,000
NEE Equity Units September 2019 [Member]
Sale of equity units [Abstract]
Amount of equity units sold			$ 1,500,000,000	$ 1,500,000,000
Stated amount of each equity unit (in dollars per share)			$ 50	$ 50
Undivided beneficial ownership interest per debenture (in hundredths)			5.00%	5.00%
Principal amount of each debenture			$ 1,000	$ 1,000
Number of shares (subject to antidilution adjustments) if purchased on final settlement date at less than or equal to low range threshold (in shares)							0.8973
Number of shares (subject to antidilution adjustments) if purchased on the final settlement date at equal to or greater than high range threshold (in shares)							0.7181
Trading period (in days) over which the market value is determined by reference to the average closing prices of the common stock			20 days
Rate of total annual distributions on equity units (in hundredths)							4.872%
Interest rate							2.10%
Rate of payments on stock purchase contracts (in hundredths)							2.772%
NEE Equity Units September 2019 [Member] | Minimum [Member]
Sale of equity units [Abstract]
The Adjusted Reference Price (in dollars per share)							$ 55.72
NEE Equity Units September 2019 [Member] | Maximum [Member]
Sale of equity units [Abstract]
Adjusted Threshold Appreciation Price							$ 69.66
NEE Equity Units February 2020 [Member]
Sale of equity units [Abstract]
Amount of equity units sold		$ 2,500,000,000
Stated amount of each equity unit (in dollars per share)		$ 50
Undivided beneficial ownership interest per debenture (in hundredths)		5.00%
Principal amount of each debenture		$ 1,000
Number of shares (subject to antidilution adjustments) if purchased on final settlement date at less than or equal to low range threshold (in shares)							0.7104
Number of shares (subject to antidilution adjustments) if purchased on the final settlement date at equal to or greater than high range threshold (in shares)							0.5681
Trading period (in days) over which the market value is determined by reference to the average closing prices of the common stock		20 days
Rate of total annual distributions on equity units (in hundredths)							5.279%
Interest rate							1.84%
Rate of payments on stock purchase contracts (in hundredths)							3.439%
NEE Equity Units February 2020 [Member] | Minimum [Member]
Sale of equity units [Abstract]
The Adjusted Reference Price (in dollars per share)							$ 70.39
NEE Equity Units February 2020 [Member] | Maximum [Member]
Sale of equity units [Abstract]
Adjusted Threshold Appreciation Price							$ 87.99
NEE Equity Units September 2020 [Member]
Sale of equity units [Abstract]
Amount of equity units sold	$ 2,000,000,000
Stated amount of each equity unit (in dollars per share)	$ 50
Undivided beneficial ownership interest per debenture (in hundredths)	5.00%
Principal amount of each debenture	$ 1,000
Number of shares (subject to antidilution adjustments) if purchased on final settlement date at less than or equal to low range threshold (in shares)							0.6776
Number of shares (subject to antidilution adjustments) if purchased on the final settlement date at equal to or greater than high range threshold (in shares)							0.5421
Trading period (in days) over which the market value is determined by reference to the average closing prices of the common stock	20 days
Rate of total annual distributions on equity units (in hundredths)							6.219%
Interest rate							0.509%
Rate of payments on stock purchase contracts (in hundredths)							5.71%
NEE Equity Units September 2020 [Member] | Minimum [Member]
Sale of equity units [Abstract]
The Adjusted Reference Price (in dollars per share)							$ 73.79
NEE Equity Units September 2020 [Member] | Maximum [Member]
Sale of equity units [Abstract]
Adjusted Threshold Appreciation Price							$ 92.24
Series I Debentures Due September 1, 2021 [Member] | NextEra Energy Capital Holdings, Inc. [Member] | Debentures [Member]
Sale of equity units [Abstract]
Interest rate								2.403%
Debt Instrument, Face Amount								$ 1,500,000,000
First mortgage bonds [Member] | FPL [Member] | Subsequent Event
Sale of equity units [Abstract]
Interest rate						2.45%
Debt Instrument, Face Amount						$ 1,500,000,000
Variable Rate Notes | FPL [Member] | Subsequent Event
Sale of equity units [Abstract]
Debt Instrument, Face Amount						$ 1,000,000,000
August 2016 Equity Units Stock Split [Member]
Sale of equity units [Abstract]
Sale of Stock, Number of Shares Issued in Transaction				9,500,000	38,200,000
Sale of Stock, Consideration Received on Transaction				$ 1,500,000,000

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Equity (Earnings Per Share) (Details) $ / shares in Units, $ in Millions		12 Months Ended
	Sep. 14, 2020 shares	Dec. 31, 2021 USD ($) $ / shares shares	Dec. 31, 2020 USD ($) $ / shares shares	Dec. 31, 2019 USD ($) $ / shares shares	Oct. 26, 2020 shares
Reconciliation of basic and diluted earnings per share of common stock [Abstract]
Net income (loss) attributable to NEE | $		$ 3,573	$ 2,919	$ 3,769
Denominator:
Weighted-average number of common shares outstanding – basic		1,962,500,000	1,959,000,000	1,927,900,000
Equity units, stock options, performance share awards, forward sale agreements and restricted stock		9,700,000	9,800,000	14,000,000.0
Weighted-average number of common shares outstanding – assuming dilution		1,972,200,000	1,968,800,000	1,941,900,000
Earnings per share attributable to NEE:
Basic | $ / shares		$ 1.82	$ 1.49	$ 1.95
Assuming dilution | $ / shares		$ 1.81	$ 1.48	$ 1.94
Antidilutive securities (in shares)		30,500,000	27,100,000	3,000,000
Stockholders' Equity Note, Stock Split, Conversion Ratio	4
Common stock, authorized (in shares)	800,000,000	3,200,000,000	3,200,000,000		3,200,000,000

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Equity (Issuance of Stock and Forward Sale Agreement) (Details) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
NEP [Member]
Class of Stock [Line Items]
Senior unsecured convertible notes outstanding	$ 500	$ 600

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Equity (Stock-Based Compensation) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Stock-based compensation
Stock based compensation costs	$ 119	$ 107	$ 100
Tax benefits related to stock-based compensation arrangements	19	$ 21	$ 17
Unrecognized stock based compensation costs	$ 148
Unrecognized stock based compensation costs weighted-average period of recognition (in years)	2 years 9 months 18 days
Common stock authorized for awards (in shares)	84,000,000
Share-based Payment Arrangement [Member]
Stock-based compensation
Number of additional shares available for grant (in shares)	0

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Equity (Restricted Stock, Performance Share Awards and Options) (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Restricted Stock Awards [Member]
Activity [Roll Forward]
Nonvested balance at beginning of year (in shares)	1,674,242
Granted (in shares)	1,013,039
Vested (in shares)	(835,919)
Forfeited (in shares)	(33,630)
Nonvested balance at end of year (in shares)	1,817,732	1,674,242
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures [Abstract]
Nonvested balance at beginning of year, weighted-average grant date fair value (in dollars per share)	$ 50.26
Granted, weighted-average grant date fair value (in dollars per share)	82.69	$ 68.25	$ 46.64
Vested, weighted-average grant date fair value (in dollars per share)	48.06
Forfeited, weighted-average grant date fair value (in dollars per share)	69.63
Nonvested balance at end of year, weighted-average grant date fair value (in dollars per share)	$ 68.09	$ 50.26
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Award vesting period	3 years
Performance Share Awards [Member]
Activity [Roll Forward]
Nonvested balance at beginning of year (in shares)	1,938,608
Granted (in shares)	1,297,680
Vested (in shares)	(1,738,904)
Forfeited (in shares)	(85,235)
Nonvested balance at end of year (in shares)	1,412,149	1,938,608
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures [Abstract]
Nonvested balance at beginning of year, weighted-average grant date fair value (in dollars per share)	$ 47.46
Granted, weighted-average grant date fair value (in dollars per share)	54.82	$ 46.09	$ 34.75
Vested, weighted-average grant date fair value (in dollars per share)	37.53
Forfeited, weighted-average grant date fair value (in dollars per share)	64.84
Nonvested balance at end of year, weighted-average grant date fair value (in dollars per share)	$ 61.22	$ 47.46
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Award vesting period	3 years
Restricted Stock and Performance Share Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures [Abstract]
Total fair value of awards vested	$ 186	$ 177	$ 125
Share-based Payment Arrangement, Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Award vesting period	3 years
Maximum term	10 years

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Equity (Assumptions and Options) (Details) - Share-based Payment Arrangement, Option [Member] - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Assumptions used to estimate the fair value of options using the Black-Scholes option pricing model [Abstract]
Expected term (years)	7 years	7 years	7 years
Option activity [Roll Forward]
Shares underlying options - Balance at beginning of year (in shares)	9,618,204
Shares underlying options - Granted (in shares)	1,220,265
Shares underlying options - Exercised (in shares)	(738,516)
Shares underlying options - forfeited (in shares)	86,641
Shares underlying options - Balance at end of year (in shares)	10,013,312	9,618,204
Shares underlying options - Exercisable (in shares)	7,235,572
Additional disclosures pertaining to options [Abstract]
Balance at beginning of year, weighted average exercise price (in dollars per share)	$ 38.32
Granted, weighted average exercise price (in dollars per share)	83.33
Exercised, weighted average exercise price (in dollars per share)	20.08
Forfeited, weighted average exercise price (in dollars per share)	71.19
Balance at end of year, weighted average exercise price (in dollars per share)	44.87	$ 38.32
Exercisable at end of year, weighted average exercise price (in dollars per share)	$ 35.35
Balance at end of year, weighted average remaining contractual term (years)	6 years
Exercisable at end of year, weighted average remaining contractual term (years)	5 years
Balance at end of year, aggregate intrinsic value	$ 486
Exercisable at end of year, aggregate intrinsic value	$ 420
Granted, weighted average grant date fair value (in dollars per share)	$ 9.82	$ 7.08	$ 5.01
Total intrinsic value of stock options exercised	$ 49,000,000	$ 71,000,000	$ 81,000,000
Cash received from option exercises	15,000,000	30,000,000	34,000,000
Tax benefit realized from options exercised	$ 11,000,000	$ 17,000,000	$ 19,000,000
Minimum [Member]
Assumptions used to estimate the fair value of options using the Black-Scholes option pricing model [Abstract]
Expected volatility (in hundredths)	17.32%	14.63%	14.20%
Expected dividends (in hundredths)	2.30%	2.50%	2.85%
Risk-free rate (in hundredths)	0.80%	0.49%	2.24%
Maximum [Member]
Assumptions used to estimate the fair value of options using the Black-Scholes option pricing model [Abstract]
Expected volatility (in hundredths)	17.75%	16.31%	14.31%
Expected dividends (in hundredths)	2.44%	2.72%	2.93%
Risk-free rate (in hundredths)	1.27%	1.52%	2.54%

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Equity (Additional Disclosures Regarding Common and Preferred Stock) (Details)	Dec. 31, 2021 $ / shares shares
NextEra Energy [Member] | Serial Preferred Stock [Member]
Preferred stock [Abstract]
Authorized (in shares)	100,000,000
Par value (in dollars per share) | $ / shares	$ 0.01
Preferred Stock Number Of Shares Outstanding	0
FPL [Member] | Preferred Stock, $100 Par Value [Member]
Preferred stock [Abstract]
Authorized (in shares)	10,414,100
Par value (in dollars per share) | $ / shares	$ 100
FPL [Member] | Preferred Stock, No Par Value [Member]
Preferred stock [Abstract]
Authorized (in shares)	5,000,000
Par value (in dollars per share) | $ / shares	$ 0
FPL [Member] | Subordinated Preferred Stock [Member] | Preferred Stock, No Par Value [Member]
Preferred stock [Abstract]
Authorized (in shares)	5,000,000
Par value (in dollars per share) | $ / shares	$ 0
Preferred Stock Number Of Shares Outstanding	0

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Equity (Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	$ (92)	$ (169)	$ (188)
Other comprehensive income (loss) before reclassifications	84	63	(3)
Amounts reclassified from AOCI	7	11	24
Total other comprehensive income, net of tax	91	74	21
Less other comprehensive loss attributable to noncontrolling interests	(1)	7	1
Acquisition of Gulf Power			(1)
AOCI Impact of Disposal of a Business		10
Accumulated other comprehensive loss, ending	0	(92)	(169)
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	6
Net Unrealized Gains (Losses) on Cash Flow Hedges
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	8	(27)	(55)
Other comprehensive income (loss) before reclassifications	0	0	0
Amounts reclassified from AOCI	6	12	29
Total other comprehensive income, net of tax	6	12	29
Less other comprehensive loss attributable to noncontrolling interests	0	0	0
Acquisition of Gulf Power			(1)
AOCI Impact of Disposal of a Business		23
Accumulated other comprehensive loss, ending	14	8	(27)
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	0
Net Unrealized Gains (Losses) on Available for Sale Securities
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	20	11	(7)
Other comprehensive income (loss) before reclassifications	(11)	12	20
Amounts reclassified from AOCI	(4)	(3)	(2)
Total other comprehensive income, net of tax	(15)	9	18
Less other comprehensive loss attributable to noncontrolling interests	0	0	0
Acquisition of Gulf Power			0
AOCI Impact of Disposal of a Business		0
Accumulated other comprehensive loss, ending	5	20	11
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	0
Defined Benefit Pension and Other Benefits Plans
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	(75)	(114)	(65)
Other comprehensive income (loss) before reclassifications	95	37	(46)
Amounts reclassified from AOCI	5	2	(3)
Total other comprehensive income, net of tax	100	39	(49)
Less other comprehensive loss attributable to noncontrolling interests	0	0	0
Acquisition of Gulf Power			0
AOCI Impact of Disposal of a Business		0
Accumulated other comprehensive loss, ending	25	(75)	(114)
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	0
Net Unrealized Gains (Losses) on Foreign Currency Translation
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	(49)	(42)	(63)
Other comprehensive income (loss) before reclassifications	(1)	13	22
Amounts reclassified from AOCI	0	0	0
Total other comprehensive income, net of tax	(1)	13	22
Less other comprehensive loss attributable to noncontrolling interests	(1)	7	1
Acquisition of Gulf Power			0
AOCI Impact of Disposal of a Business		(13)
Accumulated other comprehensive loss, ending	(49)	(49)	(42)
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	6
Other Comprehensive Income (Loss) Related to Equity Method Investees
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	4	3	2
Other comprehensive income (loss) before reclassifications	1	1	1
Amounts reclassified from AOCI	0	0	0
Total other comprehensive income, net of tax	1	1	1
Less other comprehensive loss attributable to noncontrolling interests	0	0	0
Acquisition of Gulf Power			0
AOCI Impact of Disposal of a Business		0
Accumulated other comprehensive loss, ending	5	$ 4	$ 3
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	$ 0

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Commitments and Contingencies (Estimated Planned Capital Expenditures) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($) MW
Planned Capital Expenditures [Line Items]
Guarantor Obligations, Current Carrying Value	$ 484
NEER Segment
Planned Capital Expenditures [Line Items]
2022	7,205
2023	1,690
2024	570
2025	360
2026	355
Total	10,180
Wind Expenditures [Member] | NEER Segment
Planned Capital Expenditures [Line Items]
2022	2,630
2023	240
2024	50
2025	35
2026	30
Total	$ 2,985
Planned New Generation To Be Added over 5 Years | MW	2,852
Solar Expenditures [Member] | NEER Segment
Planned Capital Expenditures [Line Items]
2022	$ 3,445
2023	1,010
2024	170
2025	25
2026	10
Total	$ 4,660
Planned New Generation To Be Added over 5 Years | MW	5,946
Battery Storage Expenditures [Member] | NEER Segment
Planned Capital Expenditures [Line Items]
2022	$ 270
2023	120
2024	0
2025	0
2026	5
Total	395
Nuclear Expenditures [Member] | NEER Segment
Planned Capital Expenditures [Line Items]
2022	200
2023	150
2024	200
2025	210
2026	210
Total	970
Rate-Regulated Transmission [Member] | NEER Segment
Planned Capital Expenditures [Line Items]
2022	220
2023	85
2024	55
2025	30
2026	30
Total	420
Other Expenditures [Member] | NEER Segment
Planned Capital Expenditures [Line Items]
2022	440
2023	85
2024	95
2025	60
2026	70
Total	750
FPL [Member]
Planned Capital Expenditures [Line Items]
2022	8,495
2023	7,630
2024	7,585
2025	7,540
2026	7,605
Total	38,855
FPL [Member] | New Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
2022	1,825
2023	1,670
2024	1,635
2025	1,210
2026	995
Total	7,335
FPL [Member] | Existing Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
2022	1,605
2023	1,465
2024	1,220
2025	685
2026	750
Total	5,725
FPL [Member] | Transmission and Distribution Expenditures [Member]
Planned Capital Expenditures [Line Items]
2022	4,035
2023	3,760
2024	3,870
2025	4,760
2026	5,075
Total	21,500
Planned Generation Capital Expenditures AFUDC First Year	50
Planned Generation Capital Expenditures AFUDC Second Year	45
Planned Generation Capital Expenditures AFUDC Third Year	40
Planned Generation Capital Expenditures AFUDC Fourth Year	15
Planned Generation Capital Expenditures AFUDC Fifth Year	0
FPL [Member] | Nuclear Fuel Expenditures [Member]
Planned Capital Expenditures [Line Items]
2022	155
2023	110
2024	145
2025	145
2026	120
Total	675
FPL [Member] | General and Other Expenditures [Member]
Planned Capital Expenditures [Line Items]
2022	875
2023	625
2024	715
2025	740
2026	665
Total	3,620
FPL [Member] | Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
Planned Generation Capital Expenditures AFUDC First Year	75
Planned Generation Capital Expenditures AFUDC Second Year	85
Planned Generation Capital Expenditures AFUDC Third Year	60
Planned Generation Capital Expenditures AFUDC Fourth Year	50
Planned Generation Capital Expenditures AFUDC Fifth Year	$ 40

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Commitments and Contingencies (Required Capacity and/or Minimum Payments Under Contracts) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
NEER Segment
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2022	$ 4,400
Capacity payments and/or minimum payments - 2023	365
Capacity payments and/or minimum payments - 2024	185
Capacity payments and/or minimum payments - 2025	85
Capacity payments and/or minimum payments - 2026	65
Capacity payments and/or minimum payments - Thereafter	570
Commitment to invest	370
Joint Obligations First Year	610
Joint Obligations Second Year	20
Joint Obligations Third Year	5
Joint Obligations Fourth Year	5
Joint Obligations Fifth Year	0
Joint ObligationsThereafter	$ 5
Mountain Valley Pipeline [Member] | NEER Segment
Long-term Purchase Commitment [Line Items]
Natural gas transportation agreement, term	20 years
Amounts Excluded from Required Capacity and or Minimum Payments, Annual Commitment	$ 70
Contract Group 1 [Member] | NEER Segment
Long-term Purchase Commitment [Line Items]
Commitment amount included in capital expenditures	4,300
FPL [Member]
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2022	1,025
Capacity payments and/or minimum payments - 2023	980
Capacity payments and/or minimum payments - 2024	955
Capacity payments and/or minimum payments - 2025	900
Capacity payments and/or minimum payments - 2026	825
Capacity payments and/or minimum payments - Thereafter	8,570
Related Party Transaction, Amounts of Transaction	419	$ 386	$ 316
FPL [Member] | Natural Gas Including Transportation and Storage Contract Minimum Payments [Member] | Sabal Trail and Florida Southeast Connection [Member]
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2022	415
Capacity payments and/or minimum payments - 2023	410
Capacity payments and/or minimum payments - 2024	410
Capacity payments and/or minimum payments - 2025	405
Capacity payments and/or minimum payments - 2026	400
Capacity payments and/or minimum payments - Thereafter	$ 5,960
Join Venture [Member] | NEER Segment
Long-term Purchase Commitment [Line Items]
Ownership interest	31.90%
Consolidation, Eliminations [Member] | FPL [Member]
Long-term Purchase Commitment [Line Items]
Related Party Transaction, Amounts of Transaction	$ 105	$ 108	$ 108

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Commitments and Contingencies (Insurance) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($)
Insurance [Abstract]
Maximum obtainable amount of private liability insurance available under Price-Anderson Act	$ 450
Amount of secondary financial protection liability insurance coverage per incident	13,100
Potential retrospective assessments under secondary financial protection system	963
Potential retrospective assessments under secondary financial protection system payable per incident per year	143
Amount of coverage per occurrence per site for property damage, decontamination and premature decommissioning risks	2,750
Amount of sublimit for non nuclear perils per occurrence per site under nuclear insurance mutual companies for property damage decontamination and premature decommissioning risks	$ 1,500
Coinsurance, percent	10.00%
Coinsurance, limit of coverage per loss per site occurrence	$ 400
Potential retrospective assessment, limited insurance coverage per occurrence per site, nuclear insurance mutual companies, property damage decontamination and premature decommissioning risks	163
Seabrook Station Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for nuclear liability secondary financial protection	16
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	2
Duane Arnold Energy Center Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	2
St Lucie Unit No 2 Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for nuclear liability secondary financial protection	20
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	4
FPL [Member]
Insurance [Abstract]
Potential retrospective assessments under secondary financial protection system	550
Potential retrospective assessments under secondary financial protection system payable per incident per year	82
Potential retrospective assessment, limited insurance coverage per occurrence per site, nuclear insurance mutual companies, property damage decontamination and premature decommissioning risks	104
Duane Arnold Energy Center Insurance [Member]
Insurance [Abstract]
Maximum obtainable amount of private liability insurance available under Price-Anderson Act	100
Amount of sublimit for non nuclear perils per occurrence per site under nuclear insurance mutual companies for property damage decontamination and premature decommissioning risks	$ 50

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Segment Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020		Dec. 31, 2019
Segment Reporting Information [Line Items]
Operating revenue		$ 17,069	$ 17,997		$ 19,204
Operating expenses - net		14,233	13,234		14,257
Gains (losses) on disposal of businesses/assets – net		77	353		406
Interest expense		1,270	1,950		2,249
Depreciation and amortization		3,924	4,052		4,216
Equity in earnings (losses) of equity method investees		666	(1,351)		66
Income Tax Expense (Benefit)		348	44		448
Net income (loss)		2,827	2,369		3,388
Net income (loss) attributable to NEE		3,573	2,919		3,769
Capital expenditures, independent power and other investments and nuclear fuel purchases		16,077	14,610		17,462
Property, plant and equipment – net		99,348	91,803		82,010
Total assets		140,912	127,684		117,691
Investment in equity method investees		6,159	5,728		7,453
Retained Earnings [Member]
Segment Reporting Information [Line Items]
Net income (loss)		3,573	2,919		3,769
FPL [Member]
Segment Reporting Information [Line Items]
Operating revenue		14,102	13,060	[1]	13,680	[1]
Operating expenses - net		9,586	8,940	[1]	10,101	[1]
Interest expense		615	641	[1]	649	[1]
Depreciation and amortization		2,266	2,526	[1]	2,771	[1]
Income Tax Expense (Benefit)		838	678	[1]	484	[1]
Net income (loss)	[2]	3,206	2,890	[1]	2,519	[1]
Capital expenditures, independent power and other investments and nuclear fuel purchases		7,570	7,679		6,485
Electric utility plant and other property – net		58,227	53,879	[3]	49,837
Total assets		78,067	71,001	[3]	65,690
FPL [Member] | Retained Earnings [Member]
Segment Reporting Information [Line Items]
Net income (loss) attributable to NEE		3,206	$ 2,890	[4]	2,519	[4]
NEER [Member]
Segment Reporting Information [Line Items]
Deemed Capital Structure			70.00%
Operating Segments [Member] | FPL Segment
Segment Reporting Information [Line Items]
Operating revenue		12,600	$ 11,662		12,192
Operating expenses - net		8,418	7,862		8,895
Gains (losses) on disposal of businesses/assets – net		1	0		5
Interest expense		588	600		594
Depreciation and amortization		1,968	2,246		2,524
Equity in earnings (losses) of equity method investees		0	0		0
Income Tax Expense (Benefit)		767	610		441
Net income (loss)		2,935	2,650		2,334
Net income (loss) attributable to NEE		2,935	2,650		2,334
Capital expenditures, independent power and other investments and nuclear fuel purchases		6,785	6,680		5,755
Electric utility plant and other property – net		52,728	48,933		45,074
Total assets		68,197	61,610		57,188
Investment in equity method investees		0	0		0
Operating Segments [Member] | NEER Segment
Segment Reporting Information [Line Items]
Operating revenue		3,053	5,046		5,639
Operating expenses - net		4,434	4,125		4,037
Gains (losses) on disposal of businesses/assets – net		78	363		402
Interest expense		367	659		873
Depreciation and amortization		1,576	1,460		1,387
Equity in earnings (losses) of equity method investees		666	(1,351)		67
Income Tax Expense (Benefit)		(395)	(416)		162
Net income (loss)		(147)	(19)		1,426
Net income (loss) attributable to NEE		599	531		1,807
Capital expenditures, independent power and other investments and nuclear fuel purchases		8,363	6,893		6,505
Property, plant and equipment – net		40,900	37,842		32,042
Total assets		62,113	55,633		51,516
Investment in equity method investees		6,150	5,713		7,453
Operating Segments [Member] | Gulf Power Segment [Member]
Segment Reporting Information [Line Items]
Operating revenue		1,503	1,398		1,487
Operating expenses - net		1,170	1,081		1,216
Gains (losses) on disposal of businesses/assets – net		0	0		0
Interest expense		28	41		55
Depreciation and amortization		297	281		247
Equity in earnings (losses) of equity method investees		0	0		0
Income Tax Expense (Benefit)		71	67		42
Net income (loss)		271	238		180
Net income (loss) attributable to NEE		271	238		180
Capital expenditures, independent power and other investments and nuclear fuel purchases		782	1,012		729
Electric utility plant and other property – net		5,499	4,946		4,763
Total assets		7,209	6,725		5,855
Investment in equity method investees		0	0		0
Corporate And Eliminations
Segment Reporting Information [Line Items]
Operating revenue		(87)	(109)		(114)
Operating expenses - net		211	166		109
Gains (losses) on disposal of businesses/assets – net		(2)	(10)		(1)
Interest expense		287	650		727
Depreciation and amortization		83	65		58
Equity in earnings (losses) of equity method investees		0	0		(1)
Income Tax Expense (Benefit)		(95)	(217)		(197)
Net income (loss)		(232)	(500)		(552)
Net income (loss) attributable to NEE		(232)	(500)		(552)
Capital expenditures, independent power and other investments and nuclear fuel purchases		147	25		4,473
Property, plant and equipment – net		221	82		131
Total assets		3,393	3,716		3,132
Investment in equity method investees		9	15		0
Corporate And Eliminations | FPL [Member]
Segment Reporting Information [Line Items]
Operating revenue		(1)	0		1
Operating expenses - net		(2)	(3)		(10)
Interest expense		(1)	0		0
Depreciation and amortization		1	(1)		0
Income Tax Expense (Benefit)		0	1		1
Net income (loss)		0	2		5
Capital expenditures, independent power and other investments and nuclear fuel purchases		3	(13)		1
Electric utility plant and other property – net		0	0		0
Total assets		$ 2,661	$ 2,666		$ 2,647

[1] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

[2] FPL's comprehensive income is the same as reported net income.

[3] Amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.

[4] 2020 and 2019 amounts have been retrospectively adjusted to reflect the merger of FPL and Gulf Power Company, see Note 6 – Merger of FPL and Gulf Power Company.