NextEra Energy (NEE) 10-K18 Feb 222021 FY Annual reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
Document and Entity Information - USD ($)	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

Audit Information

Audit Information	12 Months Ended
Audit Information	Dec. 31, 2021
Auditor Information [Abstract]
Auditor Name	Deloitte & Touche LLP
Auditor Location	Boca Raton, Florida
Auditor Firm ID	34

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Millions		12 Months Ended
CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Millions		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.

CONSOLIDATED STATEMENTS OF COMP

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

CONSOLIDATED STATEMENTS OF CO_2

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)

CONSOLIDATED BALANCE SHEETS

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.

CONSOLIDATED BALANCE SHEETS (Pa

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.

CONSOLIDATED STATEMENTS OF CASH

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.

CONSOLIDATED STATEMENTS OF COMM

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.

CONSOLIDATED STATEMENTS OF CO_3

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

Summary of Significant Accounti

Summary of Significant Accounting and Reporting Policies	12 Months Ended
Summary of Significant Accounting and Reporting Policies	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 owner ship interests in joint ventures. NEER participates in natural gas, natural gas liquids and oil production primarily through operating and non-operating ownership interests and in pipeline infrastructure through either wholly owned subsidiaries or noncontrolling or joint venture interests. NEER also invests in rate-regulated transmission facilities and transmission lines that connect its electric generation facilities to the electric grid through controlled and consolidated entities. The consolidated financial statements of NEE and FPL include the accounts of their respective controlled subsidiaries. They also include NEE's and FPL's share of the undivided interest in certain assets, liabilities, revenues and expenses. Amounts representing NEE's interest in entities it does not control, but over which it exercises significant influence, are included in investment in equity method investees; the earnings/losses of these entities is included in equity in earnings (losses) of equity method investees. Intercompany balances and transactions have been eliminated in consolidation. Certain amounts included in prior years' consolidated financial statements have been reclassified to conform to the current year's presentation. The preparation of financial statements requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of c ontingent assets and liabilities. Actual results could differ from those estimates. 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

Revenue from Contracts with Cus

Revenue from Contracts with Customers	12 Months Ended
Revenue from Contracts with Customers	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.

Derivative Instruments

Derivative Instruments	12 Months Ended
Derivative Instruments	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 ______________________ (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 Valuation Significant 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 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. 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: 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.

Non-Derivative Fair Value Measu

Non-Derivative Fair Value Measurements	12 Months Ended
Non-Derivative Fair Value Measurements	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 Estimated Carrying Estimated (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.

Income Taxes

Income Taxes	12 Months Ended
Income Taxes	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 (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.

Acquisitions Acquisitions

Acquisitions Acquisitions	12 Months Ended
Acquisitions Acquisitions	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 Jul y 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.

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
Property, Plant and Equipment	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 Gross Investment (a) Accumulated Depreciation (a) Construction (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.

Equity Method Investments

Equity Method Investments	12 Months Ended
Equity Method Investments	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.

Variable Interest Entities (VIE

Variable Interest Entities (VIEs)	12 Months Ended
Variable Interest Entities (VIEs)	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.

Leases

Leases	12 Months Ended
Leases	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 lease liabilities ROU assets lease liabilities 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.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
Asset Retirement Obligations	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.

Employee Retirement Benefits

Employee Retirement Benefits	12 Months Ended
Employee Retirement Benefits	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 Significant Significant 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 Significant Significant 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.

Debt

Debt	12 Months Ended
Debt	Dec. 31, 2021
Debt Disclosure [Abstract]
Debt	Debt Long-term debt consists of the following: December 31, 2021 2020 Maturity Balance Weighted- Balance Weighted- (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.

Equity

Equity	12 Months Ended
Equity	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- 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 Weighted- Weighted- Aggregate 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 Net Unrealized Defined Benefit Net Unrealized Other 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.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
Commitments and Contingencies	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 ______________________ (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 _______________________ (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.

Segment Information

Segment Information	12 Months Ended
Segment Information	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 NEE (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 NEE (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 NEE (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 FPL Consoli- FPL Segment Gulf Power Corp. and FPL Consoli-dated FPL Segment Gulf Power Corp. and 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.

Summary of Significant Accoun_2

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 owner ship interests in joint ventures. NEER participates in natural gas, natural gas liquids and oil production primarily through operating and non-operating ownership interests and in pipeline infrastructure through either wholly owned subsidiaries or noncontrolling or joint venture interests. NEER also invests in rate-regulated transmission facilities and transmission lines that connect its electric generation facilities to the electric grid through controlled and consolidated entities. The consolidated financial statements of NEE and FPL include the accounts of their respective controlled subsidiaries. They also include NEE's and FPL's share of the undivided interest in certain assets, liabilities, revenues and expenses. Amounts representing NEE's interest in entities it does not control, but over which it exercises significant influence, are included in investment in equity method investees; the earnings/losses of these entities is included in equity in earnings (losses) of equity method investees. Intercompany balances and transactions have been eliminated in consolidation. Certain amounts included in prior years' consolidated financial statements have been reclassified to conform to the current year's presentation. The preparation of financial statements requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of c ontingent assets and liabilities. Actual results could differ from those estimates.
NextEra Energy Partners, LP	NEP was formed in 2014 to acquire, manage and own contracted clean energy projects with stable long-term cash flows through a limited partner interest in NextEra Energy Operating Partners, LP (NEP OpCo). NEP owns or has an ownership interest in a portfolio of wind, solar and solar plus battery storage projects and long-term contracted natural gas pipelines. NEE owns a noncontrolling interest in NEP 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 ______________________ (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.
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.
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.
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.
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
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
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 includ ed in
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.
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. 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.

Summary of Significant Accoun_3

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.
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.
Schedule of Goodwill and Other Intangible Assets	NEE's goodwill and other intangible assets are as follows: Weighted- 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

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
Derivative Instruments (Tables)	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. 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 Valuation Significant 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 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.
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 —

Non-Derivative Fair Value Mea_2

Non-Derivative Fair Value Measurements (Tables)	12 Months Ended
Non-Derivative Fair Value Measurements (Tables)	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. 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 Estimated Carrying Estimated (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.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
Income Taxes (Tables)	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 (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.

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
Property, Plant and Equipment (Tables)	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 Gross Investment (a) Accumulated Depreciation (a) Construction (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.

Equity Method Investments (Tabl

Equity Method Investments (Tables)	12 Months Ended
Equity Method Investments (Tables)	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.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
Asset Retirement Obligations (Tables)	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

Employee Retirement Benefits (T

Employee Retirement Benefits (Tables)	12 Months Ended
Employee Retirement Benefits (Tables)	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 Significant Significant 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 Significant Significant 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)

Debt (Tables)

Debt (Tables)	12 Months Ended
Debt (Tables)	Dec. 31, 2021
Debt Disclosure [Abstract]
Debt Issuances and Borrowings by Subsidiaries	Long-term debt consists of the following: December 31, 2021 2020 Maturity Balance Weighted- Balance Weighted- (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.

Equity (Tables)

Equity (Tables)	12 Months Ended
Equity (Tables)	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- 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 Weighted- Weighted- Aggregate 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 Net Unrealized Defined Benefit Net Unrealized Other 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.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
Commitments and Contingencies (Tables)	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.

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
Segment Information (Tables)	Dec. 31, 2021
Segment Reporting [Abstract]
Segment Information	NEE's segment information is as follows: 2021 FPL Segment Gulf Power NEER (a) Corp. and NEE (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 NEE (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 NEE (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 FPL Consoli- FPL Segment Gulf Power Corp. and FPL Consoli-dated FPL Segment Gulf Power Corp. and 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.

Summary of Significant Accoun_4

Summary of Significant Accounting and Reporting Policies (Additional Information) (Details) € in Millions, account in Millions, $ in Millions	Oct. 29, 2021USD ($)facilityMW	Dec. 31, 2021USD ($)facilityaccountcountyMW	Dec. 31, 2020USD ($)facilityMW		Dec. 31, 2022USD ($)	Dec. 31, 2021USD ($)facilitycountyaccountunitMW	Dec. 31, 2020USD ($)facilitysolar_generation_facilityMW		Dec. 31, 2019USD ($)solar_generation_facilitywind_generation_facilityMW	Dec. 31, 2020EUR (€)facility	Jan. 01, 2020USD ($)
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.

Summary of Significant Accoun_5

Summary of Significant Accounting and Reporting Policies (FPL Base Rate Agreements) (Details) - FPL [Member]	Jan. 01, 2023USD ($)	Jan. 01, 2022USD ($)	Apr. 01, 2019USD ($)MW	Jan. 01, 2018USD ($)	Jan. 01, 2017USD ($)	Dec. 31, 2025MW	Dec. 31, 2024MW	Dec. 31, 2022USD ($)	Dec. 31, 2025USD ($)kWh$ / kWMW	Dec. 31, 2021USD ($)	Dec. 31, 2020MW
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

Summary of Significant Accoun_6

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.

Summary of Significant Accoun_7

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.

Revenue from Contracts with C_2

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

Derivative Instruments (Details

Derivative Instruments (Details) - USD ($)	12 Months Ended
Derivative Instruments (Details) - USD ($)	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

Derivative Instruments (Balance

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

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities (Significant Unobservable Inputs) (Details) - Level 3	12 Months Ended
	Dec. 31, 2021USD ($)
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

Derivative Instruments and He_2

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

Derivative Instruments (Income

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

Derivative Instruments (Net Not

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, 2021USD ($)MWhMMBTUbbl	Dec. 31, 2020USD ($)MWhMMBTUbbl
Interest Rate Swap [Member]
Derivative [Line Items]
Derivative, Notional Amount \| $	$ 11.2	$ 10.5
Foreign currency contracts
Derivative [Line Items]
Derivative, Notional Amount \| $	$ 1	$ 1
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

Derivative Instruments (Credit

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

Non-Derivative Fair Value Mea_3

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

Non-Derivative Fair Value Mea_4

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

Non-Derivative Fair Value Mea_5

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

Non-Derivative Fair Value Mea_6

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

Non-Derivative Fair Value Mea_7

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

Income Taxes - Components of In

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.

Income Taxes - Reconciliation o

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

Income Taxes - Deferred Tax Ass

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.

Income Taxes - Tax Carryforward

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

Acquisitions (Details)

Acquisitions (Details) $ in Millions	Mar. 31, 2021USD ($)stateutlitymi	Jul. 16, 2019USD ($)mi	Jan. 01, 2019USD ($)customercountymiMW	Dec. 31, 2021USD ($)county	Jan. 01, 2021USD ($)	Dec. 31, 2020USD ($)
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.

Property, Plant and Equipment -

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.

Property, Plant and Equipment_2

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

Equity Method Investments (Deta

Equity Method Investments (Details) - USD ($) $ in Millions	12 Months Ended
Equity Method Investments (Details) - USD ($) $ in Millions	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

Variable Interest Entities (V_2

Variable Interest Entities (VIEs) (Details) $ in Millions	3 Months Ended	6 Months Ended	12 Months Ended
Variable Interest Entities (VIEs) (Details) $ in Millions	Dec. 31, 2021USD ($)variable_interest_entityMW	Jun. 30, 2022MW	Dec. 31, 2021USD ($)variable_interest_entitymiMW	Dec. 31, 2019USD ($)MW	Dec. 31, 2020USD ($)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.

Leases (Details)

Leases (Details) $ in Millions	12 Months Ended
Leases (Details) $ in Millions	Dec. 31, 2021USD ($)agreement	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
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

Asset Retirement Obligations (D

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

Employee Retirement Benefits -

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

Employee Retirement Benefits _2

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

Employee Retirement Benefits _3

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

Employee Retirement Benefits _4

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

Employee Retirement Benefits _5

Employee Retirement Benefits - Expected Cash Flows (Details) - Pension Benefits [Member] $ in Millions	Dec. 31, 2021USD ($)
Defined Benefit Plan Disclosure [Line Items]
2022	$ 204
2023	208
2024	209
2025	210
2026	214
2027 – 2031	$ 1,033

Employee Retirement Benefits _6

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)

Employee Retirement Benefits _7

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

Employee Retirement Benefits _8

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)

Employee Retirement Benefits _9

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%

Debt (Schedule of Debt Instrume

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.

Debt (Minimum Annual Maturities

Debt (Minimum Annual Maturities) (Details) $ in Thousands	Dec. 31, 2021USD ($)
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

Debt (Narrative) (Details)

Debt (Narrative) (Details) - USD ($)	1 Months Ended			3 Months Ended	12 Months Ended
Debt (Narrative) (Details) - USD ($)	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

Equity (Earnings Per Share) (De

Equity (Earnings Per Share) (Details) $ / shares in Units, $ in Millions	Sep. 14, 2020shares	Dec. 31, 2021USD ($)$ / sharesshares	Dec. 31, 2020USD ($)$ / sharesshares	Dec. 31, 2019USD ($)$ / sharesshares	Oct. 26, 2020shares
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
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

Equity (Issuance of Stock and F

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

Equity (Stock-Based Compensatio

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

Equity (Restricted Stock, Perfo

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

Equity (Assumptions and Options

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%

Equity (Additional Disclosures

Equity (Additional Disclosures Regarding Common and Preferred Stock) (Details)	Dec. 31, 2021$ / sharesshares
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

Equity (Accumulated Other Compr

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

Commitments and Contingencies_2

Commitments and Contingencies (Estimated Planned Capital Expenditures) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)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

Commitments and Contingencies_3

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

Commitments and Contingencies_4

Commitments and Contingencies (Insurance) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
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

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions		12 Months Ended
Segment Information (Details) - USD ($) $ in Millions		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.