Florida Power & Light 10-K 12 Feb 21 2020 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2020	Jan. 31, 2021	Jun. 30, 2020
Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2020
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			$ 117,405,158,883
Entity Common Stock, Shares Outstanding		1,959,874,682
Entity Central Index Key	0000753308
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	FY
Amendment Flag	false
ICFR Auditor Attestation Flag	true
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

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
OPERATING REVENUES		$ 17,997	$ 19,204	$ 16,727
OPERATING EXPENSES
Fuel, purchased power and interchange		3,539	4,363	3,732
Other operations and maintenance		3,751	3,640	3,330
Storm restoration costs		183	234	3
Depreciation and amortization		4,052	4,216	3,911
Taxes other than income taxes and other - net		1,709	1,804	1,551
Total operating expenses - net		13,234	14,257	12,527
GAINS ON DISPOSAL OF BUSINESSES/ASSETS - NET		353	406	80
OPERATING INCOME		5,116	5,353	4,280
OTHER INCOME (DEDUCTIONS)
Interest Expense		(1,950)	(2,249)	(1,498)
Equity in earnings (losses) of equity method investees		(1,351)	66	358
Allowance for equity funds used during construction		93	67	96
Interest income		38	54	51
Gain on NEP deconsolidation		0	0	3,927
Gains on disposal of investments and other property - net		50	55	111
Change in unrealized gains (losses) on equity securities held in NEER's nuclear decommissioning funds - net		163	238	(189)
Other net periodic benefit income		200	185	168
Other - net		54	67	48
Total other income (deductions) - net		(2,703)	(1,517)	3,072
INCOME BEFORE INCOME TAXES		2,413	3,836	7,352
INCOME TAXES		44	448	1,576
NET INCOME		2,369	3,388	5,776
NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS		550	381	862
NET INCOME ATTRIBUTABLE TO NEE		$ 2,919	$ 3,769	$ 6,638
Earnings per share attributable to NEE:
Basic		$ 1.49	$ 1.95	$ 3.51
Assuming dilution		$ 1.48	$ 1.94	$ 3.47
FPL[Member]
OPERATING REVENUES		$ 11,662	$ 12,192	$ 11,862
OPERATING EXPENSES
Fuel, purchased power and interchange		2,616	3,256	3,250
Other operations and maintenance		1,464	1,519	1,514
Storm restoration costs		183	234	3
Depreciation and amortization		2,246	2,524	2,633
Taxes other than income taxes and other - net		1,353	1,357	1,308
Total operating expenses - net		7,862	8,890	8,708
OPERATING INCOME		3,800	3,302	3,154
OTHER INCOME (DEDUCTIONS)
Interest Expense		(600)	(594)	(541)
Allowance for equity funds used during construction		61	62	90
Other - net		(1)	5	7
Total other income (deductions) - net		(540)	(527)	(444)
INCOME BEFORE INCOME TAXES		3,260	2,775	2,710
INCOME TAXES		610	441	539
NET INCOME	[1]	$ 2,650	$ 2,334	$ 2,171
[1]	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, 2020	Dec. 31, 2019	Dec. 31, 2018
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 2,369	$ 3,388	$ 5,776
Reclassification of unrealized losses on cash flow hedges from accumulated other comprehensive income (loss) to net income	12	29	26
Net unrealized gains (losses) on securities still held	12	20	(12)
Reclassification from accumulated other comprehensive income (loss) to net income	(3)	(2)	1
Defined benefit pension and other benefits plans:
Net unrealized gain (loss) and unrecognized prior service benefit (cost)	37	(46)	(14)
Reclassification from accumulated other comprehensive income (loss) to net income	2	(3)	(3)
Net unrealized gains (losses) on foreign currency translation	13	22	(31)
Other comprehensive income related to equity method investee	1	1	4
Total other comprehensive income (loss), net of tax	74	21	(29)
Impact on NEP Deconsolidation	0	0	58
Impact of Disposal of a Business	10	0	0
COMPREHENSIVE INCOME	2,453	3,409	5,805
COMPREHENSIVE LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	543	380	862
COMPREHENSIVE INCOME ATTRIBUTABLE TO NEE	$ 2,996	$ 3,789	$ 6,667

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
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)	$ (4)	$ 8	$ 8
Net unrealized gains (losses) on securities still held, tax expense (benefit)	4	8	(5)
Reclassification from accumulated other comprehensive income (loss) to net income, tax expense (benefit)	1	(1)	(1)
Net gain (loss) and prior service benefit (cost), tax expense (benefit)	11	(14)	(5)
Reclassification from accumulated other comprehensive income (loss) to net income, tax expense (benefit)	(1)	(1)	(1)
Net unrealized gains (losses) on foreign currency translation, tax expense (benefit)	0	0	0
Other comprehensive income (loss) related to equity method investee, tax expense (benefit)	1	0	1
AOCI Impacts of NEP Deconsolidation, tax	0	0	15
Impact on Disposal, Tax	$ (19)	$ 0	$ 0

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 1,105	$ 600
Customer receivables, net of allowances	2,263	2,282
Other receivables	711	525
Materials, supplies and fossil fuel inventory	1,552	1,328
Regulatory assets	377	335
Derivatives	570	762
Other	804	1,576
Total current assets	7,382	7,408
Other assets:
Total property, plant and equipment - net	91,803	82,010
Special use funds	7,779	6,954
Investment in equity method investees	5,728	7,453
Prepaid benefit costs	1,707	1,437
Regulatory assets	3,712	3,287
Derivatives	1,647	1,624
Goodwill	4,254	4,204
Other	3,672	3,314
Total other assets	120,302	110,283
TOTAL ASSETS	127,684	117,691
Current liabilities:
Commercial paper	1,551	2,516
Other short-term debt	458	400
Current portion of long-term debt	4,138	2,124
Accounts payable	4,615	3,631
Customer deposits	474	499
Accrued interest and taxes	519	558
Derivatives	311	344
Accrued construction-related expenditures	991	1,152
Regulatory liabilities	245	320
Other	2,256	2,309
Total current liabilities	15,558	13,853
Other liabilities and deferred credits:
Long-term debt	41,944	37,543
Asset retirement obligations	3,057	3,457
Deferred income taxes	8,020	8,361
Regulatory liabilities	10,735	9,936
Derivatives	1,199	863
Other	2,242	1,831
Total other liabilities and deferred credits	67,197	61,991
TOTAL LIABILITIES	82,755	75,844
COMMITMENTS AND CONTINGENCIES
REDEEMABLE NONCONTROLLING INTERESTS	0	487
EQUITY
Common stock	20	20
Additional paid-in capital	11,222	11,955
Retained earnings	25,363	25,199
Accumulated other comprehensive loss	(92)	(169)
Total common shareholders' equity	36,513	37,005
Noncontrolling interests	8,416	4,355
TOTAL EQUITY	44,929	41,360
TOTAL LIABILITIES, REDEEMABLE NONCONTROLLING INTERESTS AND EQUITY	127,684	117,691
FPL[Member]
Current assets:
Cash and cash equivalents	20	77
Customer receivables, net of allowances	991	1,024
Other receivables	362	333
Materials, supplies and fossil fuel inventory	777	722
Regulatory assets	235	227
Other	129	136
Total current assets	2,514	2,519
Other assets:
Electric utility plant and other property - net	48,933	45,074
Special use funds	5,347	4,771
Prepaid benefit costs	1,554	1,477
Regulatory assets	2,396	2,549
Goodwill	301	300
Other	565	498
Total other assets	59,096	54,669
TOTAL ASSETS	61,610	57,188
Current liabilities:
Commercial paper	1,526	1,482
Current portion of long-term debt	54	30
Accounts payable	730	768
Customer deposits	430	459
Accrued interest and taxes	279	266
Accrued construction-related expenditures	385	426
Regulatory liabilities	206	284
Other	614	510
Total current liabilities	4,224	4,225
Other liabilities and deferred credits:
Long-term debt	15,622	14,131
Asset retirement obligations	1,783	2,268
Deferred income taxes	5,790	5,415
Regulatory liabilities	10,052	9,296
Other	399	455
Total other liabilities and deferred credits	33,646	31,565
TOTAL LIABILITIES	37,870	35,790
COMMITMENTS AND CONTINGENCIES
EQUITY
Common stock	1,373	1,373
Additional paid-in capital	12,753	10,851
Retained earnings	9,614	9,174
Total common shareholders' equity	23,740	21,398
TOTAL EQUITY	23,740	21,398
TOTAL LIABILITIES, REDEEMABLE NONCONTROLLING INTERESTS AND EQUITY	$ 61,610	$ 57,188

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Customer receivables, net of allowances	$ 67	$ 19
Total property, plant and equipment - net	91,803	82,010
Current portion of long-term debt	4,138	2,124
Accounts payable	4,615	3,631
Long-term debt	$ 41,944	$ 37,543
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)	1,960,000,000	1,956,000,000
Variable Interest Entity, Primary Beneficiary [Member]
Total property, plant and equipment - net	$ 18,084	$ 11,893
Current portion of long-term debt	27	27
Accounts payable	1,433	468
Long-term debt	493	498
Noncontrolling Interest in Variable Interest Entity	8,413	4,350
FPL[Member]
Customer receivables, net of allowances	29	3
Current portion of long-term debt	54	30
Accounts payable	730	768
Long-term debt	$ 15,622	$ 14,131
Common stock, authorized (in shares)	1,000	1,000
Common stock, par value (usd per share)	$ 0	$ 0
Common stock, issued (in shares)	1,000	1,000
Common stock, outstanding (in shares)	1,000	1,000
FPL[Member] | Variable Interest Entity, Primary Beneficiary [Member]
Current portion of long-term debt	$ 0	$ 0

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)		$ 2,369	$ 3,388	$ 5,776
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization		4,052	4,216	3,911
Nuclear fuel and other amortization		263	262	236
Unrealized losses (gains) on marked to market derivative contracts – net		533	(108)	54
Foreign currency transaction losses		45	17	16
Deferred income taxes		(78)	258	1,463
Cost recovery clauses and franchise fees		(121)	155	(225)
Equity in losses (earnings) of equity method investees		1,351	(66)	(358)
Distributions of earnings from equity method investees		456	438	328
Gains on disposal of businesses, assets and investments – net		(403)	(461)	(191)
Gain on NEP deconsolidation		0	0	(3,927)
Recoverable storm-related costs		(69)	(180)	0
Other - net		189	(141)	115
Changes in operating assets and liabilities:
Current assets		(364)	123	(631)
Noncurrent assets		(234)	(93)	(220)
Current liabilities		(6)	116	163
Noncurrent liabilities		0	231	83
Net cash provided by operating activities		7,983	8,155	6,593
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL		(6,477)	(5,560)	(5,012)
Acquisition and capital expenditures of Gulf Power		(1,012)	(5,165)	0
Independent power and other investments of NEER		(6,851)	(6,385)	(7,045)
Nuclear fuel purchases		(245)	(315)	(267)
Other capital expenditures, acquisitions and other investments		(25)	(37)	(680)
Sale of independent power and other investments of NEER		1,012	1,316	1,693
Proceeds from sale or maturity of securities in special use funds and other investments		3,916	4,008	3,410
Purchases of securities in special use funds and other investments		(4,100)	(4,160)	(3,733)
Distributions from equity method investees		0	0	637
Other - net		83	121	47
Net cash used in investing activities		(13,699)	(16,177)	(10,950)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt, including premiums and discounts		12,404	13,905	4,391
Retirements of long-term debt		(6,103)	(5,492)	(3,102)
Proceeds from differential membership investors		3,522	1,604	1,841
Net change in commercial paper		(965)	(234)	1,062
Proceeds from other short-term debt		2,158	200	5,665
Repayments of other short-term debt		(2,100)	(4,765)	(455)
Payments to related parties under a cash sweep and credit support agreement – net		(2)	(54)	(21)
Issuances of common stock/equity units - net		(92)
Issuances of common stock/equity units - net			1,494	718
Proceeds from sale of noncontrolling interests		501	99	0
Dividends on common stock		(2,743)	(2,408)	(2,101)
Other - net		(406)	(476)	(364)
Net cash provided by financing activities		6,174	3,873	7,634
Effects of currency translation on cash, cash equivalents and restricted cash		(20)	4	(7)
Net increase (decrease) in cash, cash equivalents and restricted cash		438	(4,145)	3,270
Cash, cash equivalents and restricted cash at beginning of year		1,108	5,253	1,983
Cash, cash equivalents and restricted cash at end of year		1,546	1,108	5,253
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)		1,432	1,799	1,209
Cash paid for income taxes - net		235	184	200
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions		4,445	3,573	2,138
Increase in property, plant and equipment related to an acquisition		68	0	0
Decrease in joint venture investments related to an acquisition		145	0	0
FPL[Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	[1]	2,650	2,334	2,171
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization		2,246	2,524	2,633
Nuclear fuel and other amortization		164	175	144
Deferred income taxes		513	44	180
Cost recovery clauses and franchise fees		(112)	177	(225)
Other - net		54	6	(45)
Changes in operating assets and liabilities:
Current assets		(99)	(48)	97
Noncurrent assets		(94)	(67)	(64)
Current liabilities		90	32	(509)
Noncurrent liabilities		(31)	4	40
Net cash provided by operating activities		5,381	5,181	4,422
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL		(6,477)	(5,560)	(5,012)
Nuclear fuel purchases		(203)	(195)	(123)
Proceeds from sale or maturity of securities in special use funds and other investments		2,484	2,729	2,232
Purchases of securities in special use funds and other investments		(2,565)	(2,854)	(2,402)
Other - net		64	10	239
Net cash used in investing activities		(6,697)	(5,870)	(5,066)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt, including premiums and discounts		2,952	2,493	1,742
Retirements of long-term debt		(1,427)	(95)	(1,591)
Net change in commercial paper		44	226	(431)
Repayments of other short-term debt		0	0	(250)
Capital contributions from NEE		1,900	250	1,785
Dividends on common stock		(2,210)	(2,200)	(500)
Other - net		(42)	(44)	(31)
Net cash provided by financing activities		1,217	630	724
Net increase (decrease) in cash, cash equivalents and restricted cash		(99)	(59)	80
Cash, cash equivalents and restricted cash at beginning of year		195	254	174
Cash, cash equivalents and restricted cash at end of year		96	195	254
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)		580	561	520
Cash paid for income taxes - net		126	544	415
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions		592	680	549
NEE's noncash contribution of a consolidated subsidiary - net		$ 0	$ 0	$ 526
[1]	FPL's comprehensive income is the same as reported net income.

CONSOLIDATED STATEMENTS OF COMM

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY - USD ($) $ in Millions		Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Additional Paid-in Capital [Member]Cumulative Effect, Period of Adoption, Adjustment [Member]	Accumulated Other Comprehensive Income (Loss) [Member]		Accumulated Other Comprehensive Income (Loss) [Member]Cumulative Effect, Period of Adoption, Adjustment [Member]	Retained Earnings [Member]	Retained Earnings [Member]Cumulative Effect, Period of Adoption, Adjustment [Member]		Total common Shareholders' Equity [Member]		Total common Shareholders' Equity [Member]Cumulative Effect, Period of Adoption, Adjustment [Member]		Noncontrolling Interest [Member]		Noncontrolling Interest [Member]Cumulative Effect, Period of Adoption, Adjustment [Member]	FPL[Member]		FPL[Member]Common Stock [Member]	FPL[Member]Additional Paid-in Capital [Member]	FPL[Member]Retained Earnings [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Temporary Equity, Carrying Amount, Including Portion Attributable to Noncontrolling Interests		$ 0
Balances (in shares) at Dec. 31, 2017			1,883,000,000
Beginning Balance at Dec. 31, 2017		29,531	$ 19	$ 9,086	$ 590	$ 111		$ (328)	$ 19,020	$ 280		$ 28,236		$ 542		$ 1,295		$ 5,303
BEGINNING BALANCE at Dec. 31, 2017																			$ 17,040		$ 1,373	$ 8,291	$ 7,376
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)		5,776							6,638			6,638							2,171	[1]
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest																(862)
NET INCOME		6,638																					2,171
Issuances of common stock - net				700								700
Issuances of common stock, net of issuance cost (in shares)			24,000,000
Share-based payment activity				121								121
Share-based payment activity (in shares)			4,000,000
Dividends on common stock	[2]								(2,101)			(2,101)
Other comprehensive income (loss)		(29)				(29)						(29)				0
Impact of NEP deconsolidation				0		58	[3]		0			58	[3]			(2,700)	[3]
Sales of differential membership interests to NEP																(941)
Other differential membership interests activity				(21)								(21)				1,243
Capital contributions from NEE																			1,785			1,785
Dividends to NEE		2,101																	500				(500)
NEE's contribution of a consolidated subsidiary																						526
Other (in shares)			1,000,000
Other				0					0			0				(69)						(1)	(7)
ENDING BALANCE at Dec. 31, 2018																			21,014		1,373	10,601	9,040
Ending Balance at Dec. 31, 2018		37,413	$ 19	10,476		(188)			23,837			34,144				3,269
Balance (in shares) at Dec. 31, 2018			1,912,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Temporary Equity, Interest in Subsidiary Earnings		477
Temporary Equity, Other Changes		$ (9)
Common Stock, Dividends, Per Share, Cash Paid		$ 1.11
Temporary Equity, Carrying Amount, Including Portion Attributable to Noncontrolling Interests		$ 468
Net income (loss)		3,388							3,769			3,769							2,334	[1]
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest																(371)
NET INCOME		3,769																					2,334
Issuances of common stock - net				1,470								1,470
Issuances of common stock, net of issuance cost (in shares)			40,000,000
Share-based payment activity				164								164
Share-based payment activity (in shares)			4,000,000
Dividends on common stock	[2]								(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																			250			250
Dividends to NEE		2,408																	2,200				(2,200)
Other			$ 1	(15)		(1)			1			(14)				186
ENDING BALANCE at Dec. 31, 2019		37,005																	21,398		1,373	10,851	9,174
Ending Balance at Dec. 31, 2019		$ 41,360	$ 20	11,955		(169)			25,199	$ (11)	[4]	37,005		$ (11)	[4]	4,355			$ 21,398
Balance (in shares) at Dec. 31, 2019		1,956,000,000	1,956,000,000																1,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Temporary Equity, Net Income		$ (9)
Temporary Equity, Interest in Subsidiary Earnings		29
Temporary Equity, Other Changes		$ (1)
Common Stock, Dividends, Per Share, Cash Paid		$ 1.25
Temporary Equity, Carrying Amount, Including Portion Attributable to Noncontrolling Interests		$ 487
Net income (loss)		2,369							2,919			2,919							$ 2,650	[1]
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest																(546)
NET INCOME		2,919																					2,650
Issuances of common stock - net				(92)								(92)
Issuances of common stock, net of issuance cost (in shares)			0
Share-based payment activity				153								153
Share-based payment activity (in shares)			4,000,000
Dividends on common stock	[2]								(2,743)			(2,743)
Other comprehensive income (loss)		74				67						67				7
Impact of disposal of a business				0		10			0			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																			1,900			1,900
Dividends to NEE		2,743																	2,210				(2,210)
Other				(2)					(1)			(3)				102						2	0
ENDING BALANCE at Dec. 31, 2020		36,513																	23,740		$ 1,373	$ 12,753	$ 9,614
Ending Balance at Dec. 31, 2020		$ 44,929	$ 20	$ 11,222		$ (92)			$ 25,363			$ 36,513				$ 8,416			$ 23,740
Balance (in shares) at Dec. 31, 2020		1,960,000,000	1,960,000,000																1,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Temporary Equity, Net Income		$ (4)
Temporary Equity, Interest in Subsidiary Earnings		$ (483)
Common Stock, Dividends, Per Share, Cash Paid		$ 1.40
Temporary Equity, Carrying Amount, Including Portion Attributable to Noncontrolling Interests		$ 0
[1]	FPL's comprehensive income is the same as reported net income.
[2]	Dividends per share were $1.40, $1.25 and $1.11 for the years ended December 31, 2020, 2019 and 2018, respectively
[3]	See Note 1 - Basis of Presentation.
[4]	See Note 1 - Measurement of Credit Losses on Financial Instruments.

Summary of Significant Accounti

Summary of Significant Accounting and Reporting Policies	12 Months Ended
	Dec. 31, 2020
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 (Gulf Power) merged, with FPL as the surviving entity. However, FPL will continue to be regulated as two separate ratemaking entities in the former service areas of FPL and Gulf Power until the FPSC approves consolidation of the FPL and Gulf Power rates and tariffs (see Rate Regulation - FPL 2021 Base Rate Proceeding below). FPL and Gulf Power will continue to be separate operating segments of NEE as well as FPL, through 2021. FPL's principal business is a rate-regulated electric utility which supplies electric service to more than 5.6 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. Prior years' share and share-based data have been retrospectively adjusted to reflect the four-for-one stock split of NEE common stock effective October 26, 2020 (2020 stock split). See Note 14 - Earnings Per Share. 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 and solar projects and long-term contracted natural gas pipelines. NEP was deconsolidated from NEE for financial reporting purposes in January 2018 as a result of changes made to NEP's governance structure. Subsequent to deconsolidation, NEE owns a noncontrolling interest in NEP and began reflecting its ownership interest in NEP as an equity method investment with its earnings/losses from NEP as equity in earnings (losses) of equity method investees and accounting for NextEra Energy Resources' asset sales to NEP as third-party sales in its consolidated financial statements. NEER continues to operate the projects owned by NEP and provide services to NEP under various related party operations and maintenance, administrative and management services agreements. In connection with the deconsolidation, NEE recorded an initial investment in NEP of approximately $4.4 billion based on the fair value of NEP OpCo and NEP common units that were held by subsidiaries of NEE on the deconsolidation date, which investment is included in the investment in equity method investees on NEE's consolidated balance sheets. See Note 8. The fair value was based on the market price of NEP common units as of January 1, 2018, which resulted in NEE recording a gain of approximately $3.9 billion ($3.0 billion after tax) for the year ended December 31, 2018. 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, 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 $725 million, $763 million and $738 million in 2020, 2019 and 2018, 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, 2020 2019 2020 2019 (millions) Regulatory assets: Current: Early retirement of generation facilities $ 36 $ 31 $ 32 $ 27 Acquisition of purchased power agreements 161 165 161 165 Other 180 139 42 35 Total $ 377 $ 335 $ 235 $ 227 Noncurrent: Early retirement of generation facilities $ 1,438 $ 1,004 $ 932 $ 956 Acquisition of purchased power agreements 473 634 473 634 Other 1,801 1,649 991 959 Total $ 3,712 $ 3,287 $ 2,396 $ 2,549 Regulatory liabilities: Current: Deferred clause revenues $ 215 $ 309 $ 197 $ 284 Other 30 11 9 — Total $ 245 $ 320 $ 206 $ 284 Noncurrent: Asset retirement obligation regulatory expense difference $ 3,583 $ 2,826 $ 3,583 $ 2,828 Accrued asset removal costs 1,206 1,346 1,015 1,157 Deferred taxes 4,698 4,862 4,237 4,397 Other 1,248 902 1,217 914 Total $ 10,735 $ 9,936 $ 10,052 $ 9,296 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. At December 31, 2020 and 2019, FPL had regulatory assets, net of amortization, of approximately $634 million and $799 million, respectively, (included in current and noncurrent regulatory assets on NEE's and FPL’s consolidated balance sheets) related to acquisitions during 2015, 2017 and 2018 associated with three coal-fired electric generation facilities located in Florida with which FPL had long-term purchased power agreements. The majority of these regulatory assets are being amortized over approximately nine years. All three facilities have been retired. In 2018, FPL early retired three of its generation facilities. As a result of the retirements, FPL reclassified the net book value of these units (approximately $883 million) from plant in service and other property to current and noncurrent regulatory assets. Recovery of $736 million of these regulatory assets has been deferred until FPL’s base rates are next reset in a general base rate proceeding. The remainder of these regulatory assets are being amortized over 15 years. At December 31, 2020 and 2019, the regulatory assets, net of amortization, totaled approximately $859 million and $851 million, respectively, and are included in current and noncurrent regulatory assets on NEE's and FPL's consolidated balance sheets. In October 2020, as a result of significant damage from the impacts of Hurricane Sally (see Storm Funds, Storm Reserves and Storm Cost Recovery below), Gulf Power accelerated the planned mid-2021 retirement of all coal-fired generation capability at Plant Crist. In November 2020, Gulf Power filed a petition with the FPSC to establish a regulatory asset for the underrecovered investment in Plant Crist and to defer the recovery of the regulatory asset until base rates are reset in the next general base rate proceeding. An FPSC decision is expected in March 2021. At December 31, 2020, the remaining net book value of the coal generating assets totaling approximately $462 million is reclassified to a noncurrent regulatory asset on NEE’s consolidated balance sheet. 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. Other regulatory assets and liabilities are discussed within various subsections in Note 1 below. FPL Base Rates Effective January 2017 - 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, include, among other things, the following: • New retail base rates and charges were established resulting 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 megawatts (MW) natural gas-fired combined-cycle unit in Okeechobee County, Florida that achieved commercial operation on March 31, 2019. • In addition, FPL received 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. • FPL's allowed regulatory return on common equity (ROE) is 10.55%, with a range of 9.60% to 11.60%. If FPL's earned regulatory ROE falls below 9.60%, FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.60%, any party with standing, other than FPL, may seek a review of FPL's retail base rates. • Subject to certain conditions, FPL may amortize, over the term of the 2016 rate agreement, up to $1.0 billion of depreciation reserve surplus plus the reserve amount that remained under FPL's previous rate agreement (approximately $250 million), provided that in any year of the 2016 rate agreement FPL must amortize at least enough reserve to maintain a 9.60% earned regulatory ROE but may not amortize any reserve that would result in an earned regulatory ROE in excess of 11.60%. • 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 could produce 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 to recover amounts above $400 million. See Storm Funds, Storm Reserves and Storm Cost Recovery below. FPL 2021 Base Rate Proceeding - On January 11, 2021, FPL filed a formal notification with the FPSC indicating its intent to initiate a base rate proceeding by submitting a four 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 (Recovery Act), provided for an option to elect a cash grant (convertible investment tax credits (ITCs)) for certain renewable energy property (renewable property). Convertible ITCs are recorded as a reduction in property, plant and equipment on NEE's and FPL's consolidated balance sheets and are amortized as a reduction to depreciation and amortization expense over the estimated life of the related property. At December 31, 2020 and 2019, convertible ITCs, net of amortization, were approximately $791 million ($122 million at FPL) and $824 million ($128 million at FPL). At December 31, 2020 and 2019, approximately $10 million and $10 million, respectively, of such convertible ITCs are included primarily in other receivables on NEE's consolidated balance sheets. Depreciation of FPL's electric property is provided on a straight-line basis, primarily over its average remaining useful life. FPL includes in depreciation expense a provision for fossil and solar plant dismantlement, interim asset removal costs, accretion related to asset retirement obligations (see Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below), storm recovery amortization and amortization of pre-construction costs associated with planned nuclear units recovered through a cost recovery clause. For substantially all of FPL's property, depreciation studies are typically performed and filed with the FPSC every four years. As part of FPL's 2016 rate agreement, the FPSC approved new depreciation rates which became effective January 1, 2017 and which will remain in effect until FPL's base rates are next reset in a general base rate proceeding. Reserve amortization is recorded as a reduction to (or when reversed as an increase to) accrued asset removal costs which is reflected in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. FPL used available reserve amortization to offset all of the storm restoration costs that were expensed for Hurricane Dorian, Hurricane Isaias and Tropical Storm Eta. 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 fixed targeted regulatory ROE. In order to earn the targeted regulatory ROE in each reporting period under the 2016 rate agreement, reserve amortization is calculated using a trailing thirteen-month average of retail rate base and capital structure in conjunction with the trailing twelve months regulatory retail base net operating income, which primarily includes the retail base portion of base and other revenues, net of O&M, depreciation and amortization, interest and tax expenses. In general, the net impact of these income statement line items is adjusted, in part, by reserve amortization or its reversal to earn the targeted regulatory ROE. NEER's electric plant in service 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% of a utility's plant in service balance and require more than one year to complete. FPSC rules allow construction projects below the 0.5% threshold as a component of rate base. 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, 2020 and 2019, NEER's capitalized development costs totaled approximately $571 million and $651 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, fossil and solar plants over the expected service life of each unit based on nuclear decommissioning and fossil and solar dismantlement studies periodically filed with the FPSC. In addition, FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC. As approved by the FPSC, FPL previously suspended its annual decommissioning accrual. Any differences between expense recognized for financial reporting purposes and the amount recovered through rates are reported as a regulatory liability in accordance with regulatory accounting. See Rate Regulation, Electric Plant, Depreciation and Amortization, and Asset Retirement Obligations above and Note 11. Nuclear decommissioning studies are performed at least every five years and are submitted to the FPSC for approval. FPL filed updated nuclear decommissioning studies with the FPSC in December 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 $7.0 billion, or $2.5 billion expressed in 2020 dollars. 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 2020, 2019 and 2018 fund earnings on decommissioning funds were approximately $132 million, $125 million and $94 million, respectively. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. Fossil and solar plant dismantlement studies are typically performed at least every four years and are submitted to the FPSC for approval. As part of the 2016 rate agreement, the FPSC approved an annual expense of $26 million based on FPL's 2016 fossil and solar dismantlement studies, which became effective January 1, 2017, and is recorded in depreciation and amortization expense in NEE's and FPL's consolidated statements of income, and which will remain in effect until FPL's base rates are next reset in a general base rate proceeding. At December 31, 2020, FPL's portion of the ultimate cost to dismantle its fossil and solar units is approximately $1.2 billion, or $541 million expressed in 2020 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, 2020 and 2019, NEER's ARO was approximately $1,232 million and $1,097 million, respectively, and was primarily determined using various internal and external data and applying a probability percentage to a variety of scenarios regarding the life of the plant and timing of decommissioning or dismantlement. NEER's portion of the ultimate cost of decommissioning its nuclear plants, including costs associated with spent fuel storage above what is expected to be refunded by the DOE under a spent fuel settlement agreement, is estimated to be approximately $9.5 billion, or $2.1 billion expressed in 2020 dollars. The ultimate cost to dismantle NEER's wind and solar facilities is estimated to be approximately $2.4 billion. Seabrook files a comprehensive nuclear decommissioning study with the New Hampshire Nuclear Decommissioning Financing Committee (NDFC) every four years; the most recent study was filed in 2019. Seabrook's decommissioning funding plan is also subject to annual review by the NDFC. Currently, there are no ongoing decommissioning funding requirements for Seabrook, Duane Arnold and Point Beach, however, the U.S. Nuclear Regulatory Commission (NRC), and in the case of Seabrook, the NDFC, has the authority to require additional funding in the future. NEER's portion of Seabrook's, Duane Arnold's and Point Beach's restricted funds for the payment of future expenditures to decommission these plants is included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily carried at fair value. See Note 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 fossil maintenance as incurred. FPL recognizes costs associated with planned major nuclear maintenance in accordance with regulatory treatment. FPL defers nuclear maintenance costs for each nuclear unit’s planned outage to a regulatory asset as the costs are incurred and amortizes the costs to O&M expense over the period from the end of the current outage to the end of the next planned outage. NEER uses the deferral method to account for certain planned major maintenance costs. NEER's major maintenance costs for its nuclear generation units and combustion turbines are capitalized (included in noncurrent other assets on NEE's consolidated balance sheets) and amortized to O&M expenses using the straight-line method over the period from the end of the last outage to the beginning of the next planned outage. Cash Equivalents - Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less. Restricted Cash - At December 31, 2020 and 2019, NEE had approximately $441 million ($76 million for FPL) and $508 million ($118 million for FPL), respectively, of restricted cash, of which approximately $374 million ($58 million for FPL) and $411 million ($54 million for FPL), respectively, is included in current other assets and the remaining balance is included in noncurrent other assets on NEE's and FPL's consolidated balance sheets. Restricted cash is primarily related to debt service payments, bond proceeds held for construction at FPL and margin cash collateral requirements. In addition, where offsetting positions exist, restricted cash related to margin cash collateral of $183 million is netted against derivative assets and $136 million is netted against derivative liabilities at December 31, 2020 and $139 million is netted against derivative assets and $66 million is netted against derivative liabilities at December 31, 2019. See Note 3. Measurement of Credit Losses on Financial Instruments - Effective January 1, 2020, NEE and FPL adopted an accounting standards update that provides for a new methodology, the current expected credit loss (CECL) model, to account for credit losses for certain financial assets measured at amortized cost. On January 1, 2020, NEE recorded a reduction to retained earnings of approximately $11 million representing the cumulative effect of adopting the new standards update, which primarily related to the impact of applying the CECL model to NEER's receivables. The impact of adopting the new standards update was not material to FPL. See also Note 4 - Special Use Funds. Allowance for Doubtful Accounts - 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 forecas

Revenue from Contracts with Cus

Revenue from Contracts with Customers	12 Months Ended
	Dec. 31, 2020
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 2020, 2019 and 2018, NEE’s revenue from contracts with customers was approximately $17.0 billion ($11.6 billion at FPL), $17.5 billion ($12.1 billion at FPL) and $15.4 billion ($11.8 billion at FPL), respectively. NEE's and FPL's receivables are primarily associated with revenues earned from contracts with customers, as well as derivative and lease transactions at NEER, and consist of both billed and unbilled amounts, which are recorded in customer receivables and other receivables on NEE's and FPL's consolidated balance sheets. Receivables represent unconditional rights to consideration and reflect the differences in timing of revenue recognition and cash collections. For substantially all of NEE's and FPL's receivables, regardless of the type of revenue transaction from which the receivable originated, customer and counterparty credit risk is managed in the same manner and the terms and conditions of payment are similar. FPL - FPL’s revenues are derived primarily from tariff-based sales that result from providing electricity to retail customers in Florida with no defined contractual term. Electricity sales to retail customers account for approximately 90% of FPL’s 2020 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, 2020 and 2019, FPL's unbilled revenues amounted to approximately $392 million and $389 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, 2020, FPL expects to record approximately $415 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 2021 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 2024 and certain power purchase agreements with maturity dates through 2034. As of December 31, 2020, NEER expects to record approximately $825 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
	Dec. 31, 2020
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 fuel and purchased power cost recovery clause (fuel clause). For NEE's non-rate regulated operations, predominantly NEER, essentially all changes in the derivatives' fair value for power purchases and sales, fuel sales and trading activities are recognized on a net basis in operating revenues; fuel purchases used in the production of electricity are recognized in fuel, purchased power and interchange expense; and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's consolidated statements of income. Settlement gains and losses are included within the line items in the consolidated statements of income to which they relate. Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the consolidated statements of income. For commodity derivatives, NEE believes that, where offsetting positions exist at the same location for the same time, the transactions are considered to have been netted and therefore physical delivery has been deemed not to have occurred for financial reporting purposes. Settlements related to derivative instruments are primarily recognized in net cash provided by operating activities in NEE's and FPL's consolidated statements of cash flows. For interest rate and foreign currency derivative instruments, 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, 2019 and 2018, 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) with the balance to interest expense, and $11 million ($8 million after tax) and $3 million ($2 million after tax) to interest expense, respectively, because it became probable that related future transactions being hedged would not occur. At December 31, 2020, 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 $7 million of net losses included in AOCI at December 31, 2020 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 Measurement 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, 2020 and December 31, 2019, 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, 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, 2019 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: NEE: Commodity contracts $ 1,229 $ 2,082 $ 1,739 $ (2,700) $ 2,350 Interest rate contracts $ — $ 24 $ 2 $ (17) 9 Foreign currency contracts $ — $ 26 $ — $ 1 27 Total derivative assets $ 2,386 FPL - commodity contracts $ — $ 3 $ 1 $ (1) $ 3 Liabilities: NEE: Commodity contracts $ 1,365 $ 1,446 $ 390 $ (2,625) $ 576 Interest rate contracts $ — $ 598 $ 144 $ (17) 725 Foreign currency contracts $ — $ 38 $ — $ 1 39 Total derivative liabilities $ 1,340 FPL - commodity contracts $ — $ 5 $ 9 $ (1) $ 13 Net fair value by NEE balance sheet line item: Current derivative assets (b) $ 762 Noncurrent derivative assets (c) 1,624 Total derivative assets $ 2,386 Current derivative liabilities (d) $ 344 Current other liabilities (e) 133 Noncurrent derivative liabilities 863 Total derivative liabilities $ 1,340 Net fair value by FPL balance sheet line item: Current other assets $ 3 Current other liabilities $ 12 Noncurrent other liabilities 1 Total derivative liabilities $ 13 ______________________ (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 $2 million in margin cash collateral received from counterparties. (c) Reflects the netting of approximately $139 million in margin cash collateral received from counterparties. (d) Reflects the netting of approximately $66 million in margin cash collateral paid to counterparties. (e) See Note 1 - Disposal of Businesses/Assets. At December 31, 2020 and 2019, NEE had approximately $6 million and $10 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, 2020 and 2019, NEE had approximately $315 million and $360 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, 2020 are as follows: Transaction Type Fair Value at Valuation Significant Range Weighted-average (a) Assets Liabilities (millions) Forward contracts - power $ 792 $ (1) Discounted cash flow Forward price (per MWh) $— — $137 $29 Forward contracts - gas 305 25 Discounted cash flow Forward price (per MMBtu) $1 — $8 $3 Forward contracts - congestion 27 7 Discounted cash flow Forward price (various) $(6) — $30 $— Options - power 35 10 Option models Implied correlations 40% — 84% 55% Implied volatilities 5% — 357% 84% Options - primarily gas 128 131 Option models Implied correlations 40% — 96% 55% Implied volatilities 16% — 310% 36% Full requirements and unit contingent contracts 363 121 Discounted cash flow Forward price (per MWh) $5 — $330 $46 Customer migration rate (b) —% — 122% 2% Forward contracts - other 29 12 Total $ 1,679 $ 305 ______________________ (a) Unobservable inputs were weighted by volume. (b) 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, 2020 2019 2018 NEE FPL NEE FPL NEE FPL (millions) Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year $ 1,207 $ (8) $ 647 $ (36) $ 566 $ — Realized and unrealized gains (losses): Included in earnings (a) 547 — 923 — 35 (1) Included in other comprehensive income (loss) (b) 1 — 5 — 7 — Included in regulatory assets and liabilities 2 2 1 1 (18) (18) Purchases 191 — 141 — 152 (16) Sales (c) 114 — — — — — Settlements (562) 6 (356) 25 28 (2) Issuances (123) — (87) — (115) — Impact of adoption of revenue standard — — — — (30) — Transfers in (d) 18 (1) (5) — — — Transfers out (d) (21) — (62) 2 22 1 Fair value of net derivatives based on significant unobservable inputs at December 31 $ 1,374 $ (1) $ 1,207 $ (8) $ 647 $ (36) Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date (e) $ 317 $ — $ 611 $ — $ 100 $ (1) ______________________ (a) For the years ended December 31, 2020, 2019 and 2018, realized and unrealized gains of approximately $569 million, $956 million and $48 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. (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, 2020, 2019 and 2018, unrealized gains of approximately $317 million, $638 million and $112 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, 2020 2019 2018 (millions) Commodity contracts: (a) Operating revenues $ 352 $ 762 $ 377 Fuel, purchased power and interchange — — (2) Foreign currency contracts - interest expense 8 (7) 19 Interest rate contracts - interest expense (421) (699) (280) Losses reclassified from AOCI: Interest rate contracts (b) (35) (32) (30) Foreign currency contracts - interest expense (3) (4) (4) Total $ (99) $ 20 $ 80 ______________________ (a) For the years ended December 31, 2020, 2019 and 2018, FPL recorded gains (losses) of approximately $6 million, $9 million and $(31) million, respectively, related to commodity contracts as regulatory liabilities (assets) 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); 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, 2020 December 31, 2019 Commodity Type NEE FPL NEE FPL (millions) Power (90) MWh (a) — (81) MWh (a) 1 MWh (a) Natural gas (607) MMBtu (b) 87 MMBtu (b) (1,723) MMBtu (b) 161 MMBtu (b) Oil (6) barrels — (13) barrels — ______________________ (a) Megawatt-hours (b) One million British thermal units At December 31, 2020 and 2019, NEE had interest rate contracts with a net notional amount of approximately $10.5 billion and $8.9 billion, respectively, and foreign currency contracts with a net 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, 2020 and 2019, the aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately $1.9 billion ($3 million for FPL) and $1.7 billion ($12 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 $80 million (none at FPL) and $215 million (none at FPL) at December 31, 2020 and 2019, 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 $1.2 billion ($75 million at FPL) and $1.2 billion ($35 million at FPL) at December 31, 2020 and 2019, 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 $880 million ($75 million at FPL) and $590 million ($75 million at FPL) at December 31, 2020 and 2019, 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, 2020 and 2019, applicable NEE subsidiaries have posted approximately $2 million (none at FPL) and $2 million (none at FPL), respectively, in cash and $66 million (none at FPL) and $88 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
	Dec. 31, 2020
Fair Value Disclosures [Abstract]
Non-Derivative Fair Value Measurements	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, 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 $ 78 $ — $ — $ 78 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 ______________________ (a) Includes restricted cash equivalents of approximately $111 million ($56 million for FPL) in current other assets and $42 million ($17 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 consolidated balance sheet. December 31, 2019 Level 1 Level 2 Level 3 Total (millions) Assets: Cash equivalents and restricted cash equivalents: (a) NEE - equity securities $ 363 $ — $ — $ 363 FPL - equity securities $ 156 $ — $ — $ 156 Special use funds: (b) NEE: Equity securities $ 1,875 $ 2,088 (c) $ — $ 3,963 U.S. Government and municipal bonds $ 567 $ 150 $ — $ 717 Corporate debt securities $ — $ 748 $ — $ 748 Mortgage-backed securities $ — $ 517 $ — $ 517 Other debt securities $ — $ 117 $ — $ 117 FPL: Equity securities $ 596 $ 1,895 (c) $ — $ 2,491 U.S. Government and municipal bonds $ 429 $ 106 $ — $ 535 Corporate debt securities $ — $ 533 $ — $ 533 Mortgage-backed securities $ — $ 395 $ — $ 395 Other debt securities $ — $ 111 $ — $ 111 Other investments: (d) NEE: Equity securities $ 34 $ 12 $ — $ 46 Debt securities $ 82 $ 69 $ — $ 151 ______________________ (a) Includes restricted cash equivalents of approximately $60 million ($54 million for FPL) in current other assets and $64 million ($64 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 consolidated balance sheet. 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, 2020 December 31, 2019 Carrying Estimated Carrying Estimated (millions) NEE: Special use funds (a) $ 919 $ 920 $ 892 $ 891 Other investments (b) $ 29 $ 29 $ 30 $ 30 Long-term debt, including current portion $ 46,082 $ 51,525 (c) $ 39,667 (d) $ 42,928 (c)(d) FPL: Special use funds (a) $ 718 $ 719 $ 706 $ 705 Long-term debt, including current portion $ 15,676 $ 19,470 (c) $ 14,161 $ 16,448 (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, 2020 and 2019, substantially all is Level 2 for NEE and all is Level 2 for FPL. (d) Excludes debt totaling approximately $463 million classified as held for sale, which is included in current other liabilities on NEE's consolidated balance sheet at December 31, 2019, for which the carrying amount approximates fair value. See Note 1 - Disposal of Businesses/Assets. 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 $7,703 million and $6,880 million at December 31, 2020 and 2019, respectively, ($5,271 million and $4,697 million, respectively, for FPL) and FPL's storm fund assets of $76 million and $74 million at December 31, 2020 and 2019, 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 $2,009 million and $2,030 million at December 31, 2020 and 2019, respectively ($1,521 million and $1,523 million, respectively, for FPL). Debt securities included in the nuclear decommissioning funds have a weighted-average maturity at December 31, 2020 of approximately eight years at NEE and nine years at FPL. FPL's storm fund primarily consists of debt securities with a weighted-average maturity at December 31, 2020 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 on 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, 2020 and 2019 are as follows: NEE FPL Years Ended December 31, Years Ended December 31, 2020 2019 2020 2019 (millions) Unrealized gains (losses) $ 627 $ 780 $ 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, 2020 2019 2018 2020 2019 2018 (millions) Realized gains $ 110 $ 68 $ 51 $ 83 $ 44 $ 31 Realized losses $ 70 $ 48 $ 75 $ 56 $ 29 $ 49 Proceeds from sale or maturity of securities $ 2,541 $ 3,005 $ 2,551 $ 2,162 $ 2,539 $ 2,100 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, 2020 2019 2020 2019 (millions) Unrealized gains $ 134 $ 75 $ 104 $ 58 Unrealized losses (a) $ 9 $ 7 $ 9 $ 7 Fair value $ 201 $ 314 $ 150 $ 240 ______________________ (a) Unrealized losses on available for sale debt securities in an unrealized loss position for greater than twelve months at December 31, 2020 and 2019 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 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 current legal, regulatory and political environment have caused NextEra Energy Resources to consider the investment impaired and the impairment to be other than temporary. The challenges include 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 current 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 current 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

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2020
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, 2020 2019 2018 2020 2019 2018 (millions) Federal: Current $ 105 $ 167 $ 30 $ 53 $ 348 $ 251 Deferred (148) 115 1,153 388 (29) 134 Total federal (43) 282 1,183 441 319 385 State: Current 18 23 63 44 49 91 Deferred 69 143 330 125 73 63 Total state 87 166 393 169 122 154 Total income taxes $ 44 $ 448 $ 1,576 $ 610 $ 441 $ 539 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, 2020 2019 2018 2020 2019 2018 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) 2.8 3.4 4.2 4.1 3.5 4.5 Taxes attributable to noncontrolling interests 4.8 2.1 2.5 — — — PTCs and ITCs - NEER (11.8) (7.2) (3.0) — — — Amortization of deferred regulatory credit (b) (7.2) (6.2) (1.8) (5.0) (8.1) (5.0) Foreign operations (c) (2.4) — (0.8) — — — Other - net (5.4) (1.4) (0.7) (1.4) (0.5) (0.6) Effective income tax rate 1.8 % 11.7 % 21.4 % 18.7 % 15.9 % 19.9 % _________________________ (a) 2019 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 tax reform. 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). 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, 2020 2019 2020 2019 (millions) Deferred tax liabilities: Property-related $ 10,065 $ 10,133 $ 6,791 $ 6,394 Pension 437 417 394 374 Investments in partnerships and joint ventures 2,238 2,019 3 — Other 1,730 1,618 672 685 Total deferred tax liabilities 14,470 14,187 7,860 7,453 Deferred tax assets and valuation allowance: Decommissioning reserves 290 317 290 286 Net operating loss carryforwards 299 380 2 2 Tax credit carryforwards 3,859 3,406 — — ARO and accrued asset removal costs 347 368 226 273 Regulatory liabilities 1,380 1,335 1,259 1,219 Other 755 515 293 258 Valuation allowance (a) (289) (285) — — Net deferred tax assets 6,641 6,036 2,070 2,038 Net deferred income taxes $ 7,829 $ 8,151 $ 5,790 $ 5,415 ______________________ (a) Reflects valuation allowances related to deferred state tax credits and state operating loss carryforwards, and, in 2019, also reflects valuation allowances related to the solar projects in Spain that completely offset the related deferred taxes. Deferred tax assets and liabilities are included on the consolidated balance sheets as follows: NEE FPL December 31, December 31, 2020 2019 2020 2019 (millions) Noncurrent other assets $ 191 $ 210 $ — $ — Deferred income taxes - noncurrent liabilities (8,020) (8,361) (5,790) (5,415) Net deferred income taxes $ (7,829) $ (8,151) $ (5,790) $ (5,415) The components of NEE's deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2020 are as follows: Amount Expiration (millions) Net operating loss carryforwards: Federal $ 2 2033-2037 State 280 2021-2040 Foreign 17 2021-2040 Net operating loss carryforwards $ 299 Tax credit carryforwards: Federal $ 3,508 2029-2040 State 348 (a) 2021-2045 Foreign 3 2034-2040 Tax credit carryforwards $ 3,859 ______________________ (a) Includes $191 million of ITC carryforwards with an indefinite expiration period.

Acquisitions Acquisitions

Acquisitions Acquisitions	12 Months Ended
	Dec. 31, 2020
Business Combinations [Abstract]
Acquisitions	Acquisitions Gulf Power Company - On January 1, 2019, NEE acquired the outstanding common shares of Gulf Power, a rate-regulated electric utility under the jurisdiction of the FPSC. Gulf Power serves approximately 470,000 customers in eight counties throughout northwest Florida, has approximately 9,500 miles of transmission and distribution lines and owns 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. The cash purchase price was funded through $4.5 billion of borrowings by NEECH in December 2018 under certain short-term bi-lateral term loan agreements; the proceeds of which borrowings were restricted and included in noncurrent other assets on NEE's consolidated balance sheet at December 31, 2018. Such borrowings were repaid in April 2019. 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 is 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, is 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 are 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 has been recognized on NEE's consolidated balance sheet. Goodwill associated with the Gulf Power acquisition is reflected within Corporate and Other and, for impairment testing, is included in the Gulf Power reporting unit. 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 - On January 1, 2021, FPL and Gulf Power merged, with FPL as the surviving entity. However, FPL will continue to be regulated as two separate ratemaking entities in the former service areas of FPL and Gulf Power until the FPSC approves consolidation of the FPL and Gulf Power rates and tariffs (see Note 1 - Rate Regulation - FPL 2021 Base Rate Proceeding). FPL and Gulf Power will continue to be separate operating segments of NEE as well as FPL, through 2021. See Note 16. 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 (see Note 13), $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 acquisition by NEE were transferred to FPL from Corporate and Other. Also in connection with the merger, FPL assumed Gulf Power's obligations under its revolving credit facilities. 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 at December 31, 2020, 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 September 29, 2020, a wholly owned subsidiary of NEET entered into agreements to acquire GridLiance Holdco, LP and GridLiance GP, LLC (GridLiance) for approximately $660 million, including the assumption of approximately $160 million of debt, excluding post-closing adjustments. The agreements are subject to earn-out provisions for additional payments upon completion of certain development projects. GridLiance 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 acquisition is expected to close in the first half of 2021, and is subject to, among other things, approval of the FERC and utility commissions of certain states in which GridLiance operates. NEECH guarantees the payment obligations under the acquisition agreements. Other - In July 2018, NEE acquired the outstanding common shares of the entity that owns Florida City Gas (FCG), which serves approximately 110,000 residential and commercial natural gas customers in Florida's Miami-Dade, Brevard, St. Lucie and Indian River counties with 3,700 miles of natural gas pipeline, for approximately $530 million in cash subject to certain adjustments. Upon closing, NEE transferred FCG to FPL. In December 2018, NEE acquired a 100% interest in an entity that indirectly owns Oleander Power Project, an approximately 791 MW natural gas-fired, simple-cycle combustion turbine electric generation facility located near Cocoa, Florida, and a 100% interest in an entity that owns a 65% interest in Stanton Energy Center Unit A, an approximately 660 MW combined-cycle electric generation facility located near Orlando, Florida for approximately $200 million in cash, subject to certain adjustments.

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2020
Jointly-Owned Electric Plants [Abstract]
Jointly-Owned Electric Plants	Property, Plant and Equipment Property, plant and equipment consists of the following at December 31: NEE FPL 2020 2019 2020 2019 (millions) Electric plant in service and other property $ 105,860 $ 96,093 $ 57,749 $ 54,523 Nuclear fuel 1,604 1,755 1,143 1,153 Construction work in progress 10,639 9,330 4,338 3,351 Property, plant and equipment, gross 118,103 107,178 63,230 59,027 Accumulated depreciation and amortization (26,300) (25,168) (14,297) (13,953) Property, plant and equipment - net $ 91,803 $ 82,010 $ 48,933 $ 45,074 FPL - At December 31, 2020, 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 47%, 12%, 35% and 6%, respectively; the respective amounts at December 31, 2019 were 46%, 12%, 35% and 7%. 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 3.7%, 3.9% and 3.8% for 2020, 2019 and 2018, respectively. In accordance with the 2016 rate agreement (see Note 1 - Rate Regulation - FPL Base Rates Effective January 2017), FPL recorded the reversal of reserve amortization of approximately $1 million, $357 million and $541 million in 2020, 2019 and 2018, respectively. During 2020, 2019 and 2018, FPL capitalized AFUDC at a rate of 6.22%, 6.22% and 5.97%, respectively, which amounted to approximately $79 million, $80 million and $114 million , respectively. NEER - At December 31, 2020, wind, solar and nuclear plants represented approximately 55%, 13% and 8%, respectively, of NEER's depreciable electric plant in service and other property; the respective amounts at December 31, 2019 were 54%, 12% and 10%. The estimated useful lives of NEER's plants range primarily from 30 to 35 years for wind plants, 25 to 30 years for solar plants and 23 to 47 years for nuclear plants. NEER's oil and gas production assets represented approximately 14% and 15% of NEER's depreciable electric plant in service and other property at December 31, 2020 and 2019, 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 $11.0 billion at December 31, 2020. Interest capitalized on construction projects amounted to approximately $168 million, $135 million and $94 million during 2020, 2019 and 2018, 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, 2020 Ownership Gross Investment (a) Accumulated Depreciation (a) Construction (millions) FPL: St. Lucie Unit No. 2 85 % $ 2,260 $ 999 $ 47 Scherer Unit No. 4 (b) 76 % $ 1,300 $ 502 $ 2 Gulf Power: Daniel Units Nos. 1 and 2 50 % $ 718 $ 241 $ 39 Scherer Unit No. 3 25 % $ 445 $ 168 $ 2 NEER: (c) Seabrook 88.23 % $ 1,290 $ 412 $ 53 Wyman Station Unit No. 4 91.19 % $ 30 $ 9 $ 1 Stanton 65 % $ 138 $ 13 $ — Transmission substation assets located in Seabrook, New Hampshire 88.23 % $ 114 $ 9 $ 11 ______________________ (a) Excludes nuclear fuel. (b) Together with its joint interest owner, and subject to certain approvals from the FPSC, FPL intends to retire this unit in early 2022. (c) NEER also owns an approximately 70% interest in Duane Arnold, a nuclear facility that ceased operations in August 2020.

Investments in Partnerships and

Investments in Partnerships and Joint Ventures	12 Months Ended
	Dec. 31, 2020
Investments in Partnerships and Joint Ventures [Abstract]
Investments in Partnerships and Joint Ventures	Investments in Partnerships and Joint Ventures Certain subsidiaries of NEE have noncontrolling interests in various partnerships and joint ventures, essentially all of which own or are in the process of developing natural gas pipelines or own electric generation facilities. At December 31, 2020 and 2019, NEE's investments in partnerships and joint ventures totaled approximately $5,728 million and $7,453 million, respectively, which are included in investment in equity method investees on NEE's consolidated balance sheets. NEE's interest in these partnerships and joint ventures primarily range from approximately 31% to 57%. At December 31, 2020 and 2019, the principal entities included in NEE's investments in partnerships and joint ventures were NEP OpCo, Sabal Trail Transmission, LLC (Sabal Trail), Mountain Valley Pipeline, LLC, and Silver State South Solar, LLC. Summarized combined information for these principal entities is as follows: 2020 2019 (millions) Net income $ 516 $ 128 Total assets $ 22,717 $ 20,659 Total liabilities $ 6,612 $ 6,956 Partners'/members' equity (a) $ 16,105 $ 13,703 NEE's share of underlying equity in the principal entities $ 3,927 $ 3,723 Difference between investment carrying amount and underlying equity in net assets (b) 1,312 3,153 NEE's investment carrying amount for the principal entities $ 5,239 $ 6,876 ______________________ (a) Reflects NEE's interest, as well as third-party interests, in NEP OpCo. (b) Approximately $2.8 billion in 2020 and $3.0 billion in 2019 is associated with NEP OpCo; of which approximately 70% relates to goodwill and is not being amortized; the remaining balance is being amortized primarily over a period of 20 to 28 years. The 2020 difference is net of an approximately $1.5 billion impairment charge related to NextEra Energy Resources' investment in Mountain Valley Pipeline. NextEra Energy Resources provides management, administrative and 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, 2020 and 2019, the cash sweep amounts (due to NEP and its subsidiaries) held in accounts belonging to NextEra Energy Resources or its subsidiaries were approximately $10 million and $12 million, respectively, and are included in accounts payable. Fee income related to the CSCS agreement and the service agreements totaled approximately $120 million, $101 million and $94 million for the years ended December 31, 2020, 2019 and 2018, respectively, and is included in operating revenues in NEE's consolidated statements of income. Amounts due from NEP of approximately $68 million and $53 million are included in other receivables and $32 million and $33 million are included in noncurrent other assets at December 31, 2020 and 2019, respectively. Under the CSCS agreement, NEECH or NextEra Energy Resources guaranteed or provided indemnifications, letters of credit or surety bonds totaling approximately $640 million at December 31, 2020 primarily related to obligations on behalf of NEP's subsidiaries with maturity dates ranging from

Variable Interest Entities (VIE

Variable Interest Entities (VIEs)	12 Months Ended
	Dec. 31, 2020
Variable Interest Entities [Abstract]
Variable Interest Entities (VIEs)	Variable Interest Entities (VIEs) NEER - At December 31, 2020, NEE consolidates 40 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. NextEra Energy Resources consolidates two VIEs which own and operate natural gas electric generation facilities with the capability of producing 1,450 MW. These entities sell their electric output to third parties under power sales contracts with expiration dates in 2021 and 2031. The power sales contracts provide the offtaker the ability to dispatch the facilities and require the offtaker to absorb the cost of fuel. The assets and liabilities of these VIEs were approximately $188 million and $22 million, respectively, at December 31, 2020 and $216 million and $25 million, respectively, at December 31, 2019. At December 31, 2020 and 2019, the assets of these consolidated VIEs consisted primarily of property, plant and equipment. Three indirect subsidiaries of NextEra Energy Resources have an approximately 50% ownership interest in five entities which own and operate solar photovoltaic (PV) facilities with the capability of producing a total of approximately 409 MW. Each of the three 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 five entities sell their electric output to third parties under power sales contracts with expiration dates ranging from 2035 through 2042. The five 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 $751 million and $607 million, respectively, at December 31, 2020 and $776 million and $598 million, respectively, at December 31, 2019. At December 31, 2020 and 2019, the assets and liabilities of the 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 were approximately $423 million and $68 million, respectively, at December 31, 2020, and $173 million and $29 million, respectively, at December 31, 2019. At December 31, 2020 and 2019, the assets and liabilities of this VIE consisted primarily of property, plant and equipment and accounts payable. Beginning in the fourth quarter of 2020, NextEra Energy Resources consolidates a VIE which has a 10% direct ownership interest in wind generation facilities and solar PV facilities (see Note 1 - Sale of Noncontrolling Ownership Interests) which have the capacity 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 $1.6 billion and $0.4 billion, respectively, at December 31, 2020 and consisted primarily of property, plant and equipment and accounts payable. The other 33 NextEra Energy Resources VIEs that are consolidated relate to certain subsidiaries which have sold differential membership interests in entities which own and operate wind electric generation and solar PV facilities with the capability of producing a total of approximately 10,513 MW and 778 MW, respectively. These entities 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 $16.2 billion and $1.7 billion, respectively, at December 31, 2020. There were 26 of these consolidated VIEs at December 31, 2019, and the assets and liabilities of those VIEs at such date totaled approximately $11.3 billion and $0.8 billion, respectively. At December 31, 2020 and 2019, the assets and liabilities of these VIEs consisted primarily of property, plant and equipment and accounts payable. Other - At December 31, 2020 and 2019, several NEE subsidiaries had investments totaling approximately $3,704 million ($3,124 million at FPL) and $3,247 million ($2,717 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. 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 $3,932 million and $4,254 million at December 31, 2020 and 2019, respectively. At December 31, 2020, subsidiaries of NEE had commitments to invest additional amounts in five of the entities. Such commitments are included in the NEER amounts in the table in Note 15 - Contracts.

Leases

Leases	12 Months Ended
	Dec. 31, 2020
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 2021 to 2052, 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, 2020, NEE’s ROU assets and lease liabilities for operating leases totaled approximately $535 million and $541 million, respectively; the respective amounts at December 31, 2019 were $499 million and $498 million. At December 31, 2020, NEE’s ROU assets and lease liabilities for finance leases totaled approximately $128 million and $124 million, respectively; the respective amounts at December 31, 2019 were $62 million and $56 million. NEE’s lease liabilities at December 31, 2020 and 2019 were calculated using a weighted-average incremental borrowing rate at the lease inception of 3.81% and 3.73%, respectively, for operating leases and 3.50% and 3.15%, respectively, for finance leases, and a weighted-average remaining lease term of 33 years and 31 years, respectively, for operating leases and 25 years and 14 years, respectively, for finance leases. At December 31, 2020, expected lease payments over the remaining terms of the leases were approximately $1.2 billion with no one year being material. NEE's operating lease cost for the years ended December 31, 2020 and 2019 totaled approximately $95 million and $91 million, respectively. During the year ended December 31, 2020 and 2019, NEE's ROU assets obtained in exchange for operating lease obligations totaled approximately $121 million and $450 million, respectively, and in 2019 primarily relate to leases acquired with the Gulf Power and Trans Bay acquisitions (see Note 6). Other operating and finance lease-related amounts were not material to NEE's consolidated statements of income or cash flows for the periods presented.NEE has 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, 2020 and 2019, NEE recorded a net investment in sales-type leases of approximately $47 million and $50 million, respectively, and losses at commencement of sales-type leases due to the variable nature of the lease payments of approximately $20 million for the year ended December 31, 2018, which are recorded in gains on disposal of businesses/assets - net in NEE's consolidated statements of income. At December 31, 2020, the power sales agreements have expiration dates from 2021 to 2043 and NEE expects to receive approximately $117 million of lease payments over the remaining terms of the power sales agreements with no one year being material.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2020
Asset Retirement Obligations [Abstract]
Asset Retirement Obligations	Asset Retirement ObligationsNEE'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, 2018 $ 3,135 $ 2,147 Liabilities incurred 100 1 Accretion expense 172 107 Liabilities settled (65) (a) (1) Revision in estimated cash flows - net 32 (b) 14 (b) Additions from acquisitions 132 (c) — Balances, December 31, 2019 3,506 (d) 2,268 (d) Liabilities incurred 138 — Accretion expense 169 100 Liabilities settled (53) (6) Revision in estimated cash flows - net (594) (e) (558) (e) Balances, December 31, 2020 $ 3,166 (d) $ 1,804 (d) ______________________ (a) Primarily reflects sales of ownership interests to subsidiaries of NEP. See Note 1 - Disposal of Businesses/Assets. (b) Includes an increase of approximately $75 million for additional estimated ash pond closure costs at Scherer, partly offset by a decrease of approximately $71 million due to the approval of Turkey Point Units Nos. 3 and 4 license renewals for an additional 20 years. (c) See Note 6 for 2019 acquisitions. (d) Includes the current portion of AROs as of December 31, 2020 and 2019 of approximately $109 million ($21 million for FPL) and $49 million (none for FPL), respectively, which is included in other current liabilities on NEE's and FPL's consolidated balance sheets. (e) 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. 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, 2020 $ 7,703 $ 5,271 Balances, December 31, 2019 $ 6,880 $ 4,697 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
	Dec. 31, 2020
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 $323 million ($155 million for FPL) and $313 million ($167 million for FPL) at December 31, 2020 and 2019, 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: 2020 2019 (millions) Change in pension plan assets: Fair value of plan assets at January 1 $ 4,800 $ 3,806 Actual return on plan assets 723 736 Benefit payments (209) (235) Acquisitions (a) — 493 Fair value of plan assets at December 31 $ 5,314 $ 4,800 Change in pension benefit obligation: Obligation at January 1 $ 3,363 $ 2,522 Service cost 85 80 Interest cost 92 114 Acquisitions (a) — 503 Special termination benefits (b) 16 19 Plan amendments 1 3 Actuarial losses - net (c) 259 357 Benefit payments (209) (235) Obligation at December 31 (d) $ 3,607 $ 3,363 Funded status: Prepaid pension benefit costs at NEE at December 31 $ 1,707 $ 1,437 Prepaid pension benefit costs at FPL at December 31 (e) $ 1,554 $ 1,477 _________________________ (a) Relates to substantially funded pension obligations in connection with the acquisition of Gulf Power, see Note 6 - Gulf Power Company. (b) Reflects enhanced early retirement programs. (c) Primarily driven by decrease in discount rates. (d) NEE's accumulated pension benefit obligation, which includes no assumption about future salary levels, at December 31, 2020 and 2019 was approximately $3,521 million and $3,281 million, respectively. (e) 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: 2020 2019 (millions) Unrecognized prior service benefit (net of $1 and $2 tax expense, respectively) $ 2 $ 2 Unrecognized losses (net of $24 and $37 tax benefit, respectively) (60) (108) Total $ (58) $ (106) NEE's unrecognized amounts included in regulatory assets yet to be recognized as components of net prepaid pension benefit costs are as follows: 2020 2019 (millions) Unrecognized prior service benefit $ (1) $ (2) Unrecognized losses 163 263 Total $ 162 $ 261 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. 2020 2019 Discount rate (a) 2.53 % 3.22 % Salary increase 4.40 % 4.40 % Weighted-average interest crediting rate 3.82 % 3.83 % _________________________ (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, 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. December 31, 2019 (a) Quoted Prices Significant Significant Total (millions) Equity securities (b) $ 1,593 $ 9 $ 3 $ 1,605 Equity commingled vehicles (c) — 706 — 706 U.S. Government and municipal bonds 95 7 — 102 Corporate debt securities (d) — 247 — 247 Asset-backed securities — 416 — 416 Debt security commingled vehicles (e) 47 143 — 190 Convertible securities (f) 32 372 — 404 Total investments in the fair value hierarchy $ 1,767 $ 1,900 $ 3 3,670 Total investments measured at net asset value (g) 1,130 Total fair value of plan assets $ 4,800 ______________________ (a) See Notes 3 and 4 for discussion of fair value measurement techniques and inputs. (b) Includes foreign investments of $741 million. (c) Includes foreign investments of $141 million. (d) Includes foreign investments of $76 million. (e) Includes foreign investments of $5 million. (f) Includes foreign investments of $20 million. (g) Includes foreign investments of $190 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): 2021 $ 228 2022 $ 200 2023 $ 202 2024 $ 204 2025 $ 206 2026 - 2030 $ 1,024 Net Periodic Income - The components of net periodic income for the plans are as follows: Pension Benefits Postretirement Benefits 2020 2019 2018 2020 2019 2018 (millions) Service cost $ 85 $ 80 $ 70 $ 1 $ 1 $ 1 Interest cost 92 114 82 8 9 7 Expected return on plan assets (321) (312) (276) — — — Amortization of actuarial loss 18 — — 3 — — Amortization of prior service benefit (1) (1) (1) (16) (15) (15) Special termination benefits 16 19 35 — — — Net periodic income at NEE $ (111) $ (100) $ (90) $ (4) $ (5) $ (7) Net periodic income allocated to FPL $ (77) $ (71) $ (57) $ (3) $ (4) $ (6) Other Comprehensive Income - The components of net periodic income recognized in OCI for the pension plan are as follows: 2020 2019 2018 (millions) Net gains (losses) (net of $13 tax expense, $10 tax benefit and $4 tax benefit, respectively) $ 42 $ (36) $ (13) Amortization of unrecognized losses (net of $1 tax expense) 5 — — Total $ 47 $ (36) $ (13) Regulatory Assets (Liabilities) - The components of net periodic income recognized during the year in regulatory assets (liabilities) for the pension plan are as follows: 2020 2019 (millions) Prior service cost $ 1 $ — Unrecognized gains (89) (113) Amortization of prior service cost 1 $ 1 Amortization of unrecognized losses (12) — Total $ (99) $ (112) The assumptions used to determine net periodic pension income for the pension plan are as follows: 2020 2019 2018 Discount rate 3.22 % 4.26 % 3.59 % Salary increase 4.40 % 4.40 % 4.10 % Expected long-term rate of return, net of investment management fees (a) 7.35 % 7.35 % 7.35 % Weighted-average interest crediting rate 3.83 % 3.88 % 3.94 % ______________________ (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
	Dec. 31, 2020
Debt Disclosure [Abstract]
Debt	Debt Long-term debt consists of the following: December 31, 2020 2019 Maturity Balance Weighted- Balance Weighted- (millions) (millions) FPL: (a) First mortgage bonds - fixed 2023-2049 $ 13,090 4.32 % $ 12,005 4.46 % Pollution control, solid waste disposal and industrial development revenue bonds - primarily variable (b) 2021-2049 948 0.12 % 1,076 1.67 % Senior unsecured notes - variable (c)(d) 2023-2070 1,806 0.44 % 1,236 2.18 % Unamortized debt issuance costs and discount (168) (156) Total long-term debt of FPL 15,676 14,161 Less current portion of long-term debt 54 30 Long-term debt of FPL, excluding current portion 15,622 14,131 GULF POWER: (a) Senior unsecured notes - fixed 2022-2044 815 4.05 % 990 4.17 % Other long-term debt - primarily variable (b) 2021-2050 759 0.70 % 709 1.93 % Unamortized debt issuance costs and discount (14) (14) Total long-term debt of Gulf Power 1,560 1,685 Less current portion of long-term debt 300 175 Long-term debt of Gulf Power, excluding current portion 1,260 1,510 NEER: NextEra Energy Resources: Senior secured limited-recourse long-term debt - primarily variable (d)(e) 2024-2049 3,325 2.33 % 3,419 3.79 % Other long-term debt - primarily variable (d)(e) 2024-2040 450 2.72 % 440 (f) 3.78 % NEET - long-term debt - primarily fixed (e) 2021-2049 937 3.09 % 837 3.50 % Unamortized debt issuance costs and premium (65) (74) Total long-term debt of NEER 4,647 4,622 Less current portion of long-term debt 239 215 Long-term debt of NEER, excluding current portion 4,408 4,407 NEECH: Debentures - fixed (e) 2021-2030 11,540 2.86 % 9,550 3.05 % Debentures - variable (d) 2021-2022 1,225 0.80 % 1,375 3.00 % Debentures, related to NEE's equity units - fixed 2024-2025 6,000 1.46 % 1,500 2.10 % Junior subordinated debentures - primarily fixed (e) 2057-2079 3,693 4.78 % 4,643 5.13 % Japanese yen denominated long-term debt - primarily variable (d)(e)(g) 2023-2030 650 1.49 % 645 3.10 % Australian dollar denominated long-term debt - fixed (g) 2026 385 2.20 % 351 2.59 % Other long-term debt - fixed 2021 221 0.92 % 524 2.00 % Other long-term debt - variable (d) 2021 600 0.70 % 750 2.60 % Unamortized debt issuance costs, premium and discount (115) (139) Total long-term debt of NEECH 24,199 19,199 Less current portion of long-term debt 3,545 1,704 Long-term debt of NEECH, excluding current portion 20,654 17,495 Total long-term debt $ 41,944 $ 37,543 ______________________ (a) See Note 6 - Merger of FPL and Gulf Power regarding FPL's assumption of all of Gulf Power's outstanding debt on January 1, 2021. (b) 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 or Gulf Power, as the case may be, would be required to purchase the variable rate tax exempt bonds. At December 31, 2020, variable rate tax exempt bonds totaled approximately $948 million at FPL and $426 million at Gulf Power. All variable rate tax exempt bonds tendered for purchase have been successfully remarketed. FPL's and Gulf Power's syndicated revolving credit facilities, as the case may be, 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. Gulf Power's remaining debt is primarily variable which is based on an underlying index plus a margin. (c) Includes approximately $556 million of floating rate notes that permit individual noteholders to require repayment prior to maturity. FPL’s syndicated revolving credit facilities are available to support the purchase of the senior unsecured notes. (d) Variable rate is based on an underlying index plus a specified margin. (e) Interest rate contracts, primarily swaps, have been entered into with respect to certain of these debt issuances. See Note 3. (f) Excludes approximately $463 million classified as held for sale, which is included in current other liabilities on NEE's consolidated balance sheets. See Note 1 - Disposal of Businesses/Assets. (g) Foreign currency contracts have been entered into with respect to these debt issuances. See Note 3. As of December 31, 2020, minimum annual maturities of long - term debt for NEE are approximately $4,138 million, $2,471 million, $3,329 million, $3,564 million and $7,640 million for 2021, 2022, 2023, 2024 and 2025, respectively. The respective amounts for FPL are approximately $54 million, $96 million, $1,765 million, $646 million and $1,700 million. At December 31, 2020 and 2019, short-term borrowings had a weighted-average interest rate of 0.35% (0.17% for FPL) and 1.95% (1.80% for FPL), respectively. Subsidiaries of NEE, including FPL, had credit facilities with available capacity at December 31, 2020 of approximately $11.9 billion ($3.6 billion for FPL), of which approximately $11.8 billion ($3.6 billion for FPL) relate to revolving line of credit facilities and $65 million (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 at December 31, 2020 of up to approximately $2.0 billion ($572 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. See Note 6 - Merger of FPL and Gulf Power regarding FPL's assumption of Gulf Power's revolving credit facilities on January 1, 2021. 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 2018, NEECH completed a remarketing of approximately $700 million aggregate principal amount of its Series H Debentures due September 1, 2020 (Series H Debentures) that were issued in September 2015 as components of equity units issued concurrently by NEE (September 2015 equity units). The Series H Debentures were fully and unconditionally guaranteed by NEE. In connection with the remarketing of the Series H Debentures, the interest rate on the Series H Debentures was reset to 3.342% per year, and interest was payable on March 1 and September 1 of each year, commencing September 1, 2018. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the September 2015 equity units, in the third quarter of 2018, NEE issued approximately 6.2 million shares of common stock (24.9 million shares after giving effect to the 2020 stock split) in exchange for $700 million . 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 2020 stock split) in exchange for $1.5 billion. As a result of the 2020 stock split (and other adjustments related to the current dividend rate with respect to the 4.872% Corporate Units), 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, 2020. 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, 2020, the number of shares issued per equity unit would (subject to antidilution adjustments) range from 0.8940 shares if the applicable market value of a share of NEE common stock is less than or equal to $55.93 (the adjusted reference price) to 0.7156 shares if the applicable market value of a share is equal to or greater than $69.91 (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, 2020, the number of shares issued per equity unit would (subject to antidilution adjustments) range from 0.7092 shares if the applicable market value of a share of NEE common stock is less than or equal to $70.51 (the adjusted reference price) to 0.5672 shares if the applicable market value of a share is equal to or greater than $88.14 (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, 2020, the number of shares issued per equity unit would (subject to antidilution adjustments) range from 0.6764 shares if the applicable market value of a share of NEE common stock is less than or equal to $73.93 (the adjusted reference price) to 0.5412 shares if the applicable market value of a share is equal to or greater than $92.41 (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.

Equity

Equity	12 Months Ended
	Dec. 31, 2020
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, 2020 2019 2018 (millions, except per share amounts) Numerator: Net income attributable to NEE - basic $ 2,919 $ 3,769 $ 6,638 Adjustment for the impact of dilutive securities at NEP (a) — — (19) Net income attributable to NEE - assuming dilution $ 2,919 $ 3,769 $ 6,619 Denominator: Weighted-average number of common shares outstanding - basic 1,959.0 1,927.9 1,892.8 Equity units, stock options, performance share awards and restricted stock (b) 9.8 14.0 15.1 Weighted-average number of common shares outstanding - assuming dilution 1,968.8 1,941.9 1,907.9 Earnings per share attributable to NEE: Basic $ 1.49 $ 1.95 $ 3.51 Assuming dilution $ 1.48 $ 1.94 $ 3.47 _________ _____________ (a) The 2018 adjustment is related to both the NEP Series A convertible preferred units and the NEP senior unsecured convertible notes issued in 2017 (see Potentially Dilutive Securities at NEP below). (b) 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 27.1 million, 3.0 million and 0.5 million for the years ended December 31, 2020, 2019 and 2018, 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. Prior years' share and share-based data included in NEE's consolidated financial statements have been retrospectively adjusted to reflect the 2020 stock split. Potentially Dilutive Securities at NEP - Convertible preferred units representing limited partner interests in NEP (NEP preferred units) and NEP senior unsecured convertible notes, when outstanding, are potentially dilutive securities to NEE. In 2017, NEP issued approximately $550 million of Series A NEP preferred units and $300 million of senior unsecured convertible notes. As of December 31, 2020, all of the Series A NEP preferred units and all of the senior unsecured convertible notes issued in 2017 were no longer outstanding. In December 2020, NEP issued $600 million 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, 2020, 2019 and 2018 includes approximately $107 million, $100 million and $82 million, respectively, of compensation costs and $21 million, $17 million and $21 million, respectively, of income tax benefits related to stock-based compensation arrangements. Compensation cost capitalized for the years ended December 31, 2020, 2019 and 2018 was not material. At December 31, 2020, there were approximately $109 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 1.7 years. At December 31, 2020, approximately 60 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) Amended and Restated 2011 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 The activity in restricted stock and performance share awards for the year ended December 31, 2020 was as follows: Shares Weighted- Restricted Stock: Nonvested balance, January 1, 2020 1,980,592 $ 39.93 Granted 631,186 $ 68.25 Vested (870,780) $ 39.58 Forfeited (66,756) $ 49.21 Nonvested balance, December 31, 2020 1,674,242 $ 50.26 Performance Share Awards: Nonvested balance, January 1, 2020 2,680,584 $ 35.61 Granted 1,535,436 $ 46.09 Vested (2,081,264) $ 32.93 Forfeited (196,148) $ 44.85 Nonvested balance, December 31, 2020 1,938,608 $ 47.46 The weighted-average grant date fair value per share of restricted stock granted for the years ended December 31, 2019 and 2018 was $46.64 and $38.92 respectively. The weighted-average grant date fair value per share of performance share awards granted for the years ended December 31, 2019 and 2018 was $34.75 and $31.06, respectively. The total fair value of restricted stock and performance share awards vested was $177 million, $125 million and $115 million for the years ended December 31, 2020, 2019 and 2018, 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: 2020 2019 2018 Expected volatility (a) 14.63 – 16.31% 14.20 - 14.31% 14.41% Expected dividends 2.50 – 2.72% 2.85 - 2.93% 3.05% Expected term (years) (b) 7.0 7.0 7.0 Risk-free rate 0.49 – 1.52% 2.24 - 2.54% 2.83% ______________________ (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, 2020 was as follows: Shares Weighted- Weighted- Aggregate Balance, January 1, 2020 9,666,752 $ 30.77 Granted 1,519,712 $ 68.76 Exercised (1,513,324) $ 64.53 Forfeited (54,936) $ 59.18 Balance, December 31, 2020 9,618,204 $ 38.32 6.2 $ 373 Exercisable, December 31, 2020 6,382,356 $ 29.69 5.1 $ 303 The weighted-average grant date fair value of options granted was $7.08, $5.01 and $4.51 per share for the years ended December 31, 2020, 2019 and 2018, respectively. The total intrinsic value of stock options exercised was approximately $71 million, $81 million and $35 million for the years ended December 31, 2020, 2019 and 2018, respectively. Cash received from option exercises was approximately $30 million, $34 million and $18 million for the years ended December 31, 2020, 2019 and 2018, respectively. The tax benefits realized from options exercised were approximately $17 million, $19 million and $9 million for the years ended December 31, 2020, 2019 and 2018, 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, 2017 $ (77) $ 316 $ (39) $ (69) $ (20) $ 111 Other comprehensive income (loss) before reclassifications — (12) (14) (31) 4 (53) Amounts reclassified from AOCI 26 (a) 1 (b) (3) (c) — — 24 Net other comprehensive income (loss) 26 (11) (17) (31) 4 (29) Impact of NEP deconsolidation (d) 3 — — 37 18 58 Adoption of accounting standards updates (7) (312) (9) — — (328) 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 (e) — — (13) (e) — 10 Balances, December 31, 2020 $ 8 $ 20 $ (75) $ (49) $ 4 $ (92) Attributable to noncontrolling interests $ — $ — $ — $ (8) $ — $ (8) Attributable to NEE $ 8 $ 20 $ (75) $ (41) $ 4 $ (84) ———————————— (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 and included in gain on NEP deconsolidation. See Note 1 - Basis of Presentation. (e) 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.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2020
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 and Gulf Power 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 joint ventures for the development and construction of natural gas pipeline assets and a rate-regulated transmission facility. Also see Note 6 - GridLiance. At December 31, 2020, estimated capital expenditures for 2021 through 2025 for which applicable internal approvals (and also, if required, regulatory approvals such as FPSC approvals for FPL and Gulf Power) have been received were as follows: 2021 2022 2023 2024 2025 Total (millions) FPL: Generation: (a) New (b) $ 780 $ 880 $ 680 $ 540 $ 530 $ 3,410 Existing 1,085 1,155 1,045 1,010 750 5,045 Transmission and distribution (c) 4,065 3,665 3,825 4,290 4,490 20,335 Nuclear fuel 220 170 120 145 145 800 General and other 740 760 810 725 780 3,815 Total $ 6,890 $ 6,630 $ 6,480 $ 6,710 $ 6,695 $ 33,405 Gulf Power $ 860 $ 695 $ 625 $ 685 $ 685 $ 3,550 NEER: Wind (d) $ 1,770 $ 60 $ 15 $ 15 $ 5 $ 1,865 Solar (e) 1,565 340 185 — — 2,090 Battery storage 355 — — — — 355 Nuclear, including nuclear fuel 230 190 145 190 200 955 Natural gas pipelines (f) 285 165 — — — 450 Rate-regulated transmission 205 25 10 15 30 285 Other 730 125 100 75 60 1,090 Total $ 5,140 $ 905 $ 455 $ 295 $ 295 $ 7,090 ______________________ (a) Includes AFUDC of approximately $75 million, $50 million, $25 million, $15 million and $15 million for 2021 through 2025, respectively. (b) Includes land, generation structures, transmission interconnection and integration and licensing. (c) Includes AFUDC of approximately $50 million, $50 million, $40 million, $55 million and $45 million for 2021 through 2025, respectively. (d) Consists of capital expenditures for new wind projects, repowering of existing wind projects and related transmission totaling approximately 2,394 MW. (e) Includes capital expenditures for new solar projects and related transmission totaling approximately 2,354 MW. (f) Construction of natural gas pipelines are subject to certain conditions, including applicable regulatory approvals and in certain cases the resolution of legal challenges. 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 $288 million at December 31, 2020. These obligations primarily related to guaranteeing the residual value of a financing lease. 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, 2020, NEER has entered into contracts with expiration dates ranging from late February 2021 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 natural gas pipelines and a rate-regulated transmission facility. Approximately $3.4 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 ranging from late February 2021 through 2041. The required capacity and/or minimum payments under contracts, including those discussed above at December 31, 2020, were estimated as follows: 2021 2022 2023 2024 2025 Thereafter (millions) FPL (a) $ 1,030 $ 970 $ 950 $ 940 $ 890 $ 9,380 NEER (b)(c)(d) $ 3,250 $ 530 $ 210 $ 210 $ 140 $ 1,635 _______________________ (a) Includes approximately $415 million, $415 million, $410 million, $410 million, $405 million and $6,360 million in 2021 through 2025 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 $386 million, $316 million and $303 million for the years ended December 31, 2020, 2019 and 2018, respectively, of which $108 million, $108 million and $95 million, respectively, were eliminated in consolidation at NEE. (b) Includes approximately $25 million, $70 million, $70 million, $70 million and $1,155 million for 2022 through 2025 and thereafter, respectively, of firm commitments related to a natural gas transportation agreement with a joint venture, in which NEER has a 31.5% equity investment, that is constructing a natural gas pipeline. These firm commitments are subject to the completion of construction of the pipeline which is currently estimated to be in 2022. (c) Includes approximately $85 million of commitments to invest in technology investments through 2029. (d) Includes approximately $480 million, $20 million, $20 million, $10 million, $10 million and $5 million for 2021 through 2025 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, and participates in a secondary financial protection system, which provides up to $13.3 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 $1.1 billion ($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 $164 million ($82 million for FPL) per incident per year. NEE 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 $16 million, $41 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 sublimit of $500 million. NEE participates in co-insurance of 10% of the first $400 million of losses per site per occurrence. 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 $173 million ($106 million for FPL), plus any applicable taxes, in retrospective premiums in a policy year. NEE 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, $4 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 either FPL's or Gulf Power's future storm restoration costs exceed their respective storm reserve, FPL and Gulf Power may recover their storm restoration costs, 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 or Gulf Power, would be borne by NEE and either FPL or Gulf Power, and could have a material adverse effect on NEE's and FPL's financial condition, results of operations and liquidity. Coronavirus Pandemic - NEE and FPL are closely monitoring the global outbreak of the novel coronavirus (COVID-19) and are taking steps intended to mitigate the potential risks to NEE and FPL posed by COVID-19. NEE, including FPL, has implemented its pandemic plan, which includes putting in place various processes and procedures to limit the impact on its business, as well as the spread of the virus in its workforce. NEE and its subsidiaries, including FPL, have been able to access the capital markets. To date, there has been no material impact on NEE’s or FPL’s workforce, operations, financial performance, liquidity or on their supply chain as a result of COVID-19; however, the ultimate severity or duration of the outbreak or its effects on the global, national or local economy, the capital and credit markets, or NEE’s and FPL’s workforce, customers and suppliers are uncertain. NEE and FPL cannot predict whether COVID-19 will have a material impact on their businesses, financial condition, liquidity or results of operations.

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2020
Segment Reporting [Abstract]
Segment Information	Segment Information The table below presents information for NEE's reportable segments, FPL, a rate-regulated utility business, and NEER, which is comprised of competitive energy and rate-regulated transmission businesses, as well as for Gulf Power, a rate-regulated utility business acquired by NEE in January 2019. Corporate and Other represents other business activities and includes eliminating entries. See Note 2 for information regarding NEE's and FPL's operating revenues. NEE's segment information is as follows: 2020 FPL Gulf Power (a) NEER (b) 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 Interest income $ 2 $ 2 $ 28 $ 6 $ 38 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) (c) $ 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 2019 FPL Gulf Power (a) NEER (b) Corp. and NEE (millions) Operating revenues $ 12,192 $ 1,487 $ 5,639 $ (114) $ 19,204 Operating expenses - net (d) $ 8,895 $ 1,216 $ 4,037 $ 109 $ 14,257 Gains (losses) on disposal of businesses/assets - net (d) $ 5 $ — $ 402 $ (1) $ 406 Interest expense $ 594 $ 55 $ 873 $ 727 $ 2,249 Interest income $ 5 $ 3 $ 38 $ 8 $ 54 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) (c) $ 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) See Note 6 - Gulf Power Company and - Merger of FPL and Gulf Power. (b) 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. (c) NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 - Income Taxes. (d) FPL's income statement line for total operating expenses - net includes gains (losses) on disposal of businesses/assets - net. 2018 FPL NEER (a)(b) Corp. and NEE (millions) Operating revenues $ 11,862 $ 4,984 $ (119) $ 16,727 Operating expenses - net (c) $ 8,714 $ 3,698 $ 115 $ 12,527 Gains (losses) on disposal of businesses/assets - net (c) $ 6 $ 82 $ (8) $ 80 Interest expense $ 541 $ 595 $ 362 $ 1,498 Interest income $ 4 $ 40 $ 7 $ 51 Depreciation and amortization $ 2,633 $ 1,230 $ 48 $ 3,911 Equity in earnings of equity method investees $ — $ 321 $ 37 $ 358 Income tax expense (benefit) (d) $ 539 $ 1,196 $ (159) $ 1,576 Net income (loss) $ 2,171 $ 3,842 $ (237) $ 5,776 Net income (loss) attributable to NEE $ 2,171 $ 4,704 $ (237) $ 6,638 Capital expenditures, independent power and other investments and nuclear fuel purchases $ 5,135 $ 7,189 $ 680 $ 13,004 Property, plant and equipment - net $ 41,499 $ 28,602 $ 233 $ 70,334 Total assets $ 53,484 $ 44,509 $ 5,709 $ 103,702 Investment in equity method investees $ — $ 6,521 $ 227 $ 6,748 _________________________ (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) NEP was deconsolidated from NEER in January 2018. See Note 1 - Basis of Presentation. (c) FPL's income statement line for total operating expenses - net includes gains (losses) on disposal of businesses/assets - net. (d) NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 - Income Taxes.

Quarterly Data (Unaudited)

Quarterly Data (Unaudited)	12 Months Ended
	Dec. 31, 2020
Quarterly Data (Unaudited) [Abstract]
Quarterly Data (Unaudited)	Quarterly Data (Unaudited) NEE's previously reported share-based information in the following table has been retrospectively adjusted to reflect the 2020 stock split. See Note 14 - Earnings Per Share. March 31 June 30 September 30 December 31 2020 Earnings per share attributable to NEE - basic (a) $ 0.21 $ 0.65 $ 0.63 $ — Earnings per share attributable to NEE - assuming dilution (a) $ 0.21 $ 0.65 $ 0.62 $ — Dividends per share $ 0.35 $ 0.35 $ 0.35 $ 0.35 High-low common stock sales prices $70.84 - $43.70 $65.56 - $53.26 $74.82 - $59.58 $83.34 - $69.63 2019 Earnings per share attributable to NEE - basic (a) $ 0.36 $ 0.64 $ 0.46 $ 0.50 Earnings per share attributable to NEE - assuming dilution (a) $ 0.35 $ 0.64 $ 0.45 $ 0.50 Dividends per share $ 0.3125 $ 0.3125 $ 0.3125 $ 0.3125 High-low common stock sales prices $48.89 - $42.17 $52.23 - $46.82 $58.36 - $50.27 $61.25 - $55.17 ______________________ (a) The sum of the quarterly amounts may not equal the total for the year due to rounding and changes in weighted-average number of common shares outstanding.

Summary of Significant Accoun_2

Summary of Significant Accounting and Reporting Policies (Policies)	12 Months Ended
	Dec. 31, 2020
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 (Gulf Power) merged, with FPL as the surviving entity. However, FPL will continue to be regulated as two separate ratemaking entities in the former service areas of FPL and Gulf Power until the FPSC approves consolidation of the FPL and Gulf Power rates and tariffs (see Rate Regulation - FPL 2021 Base Rate Proceeding below). FPL and Gulf Power will continue to be separate operating segments of NEE as well as FPL, through 2021. FPL's principal business is a rate-regulated electric utility which supplies electric service to more than 5.6 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. Prior years' share and share-based data have been retrospectively adjusted to reflect the four-for-one stock split of NEE common stock effective October 26, 2020 (2020 stock split). See Note 14 - Earnings Per Share. 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 and solar projects and long-term contracted natural gas pipelines. NEP was deconsolidated from NEE for financial reporting purposes in January 2018 as a result of changes made to NEP's governance structure. Subsequent to deconsolidation, NEE owns a noncontrolling interest in NEP and began reflecting its ownership interest in NEP as an equity method investment with its earnings/losses from NEP as equity in earnings (losses) of equity method investees and accounting for NextEra Energy Resources' asset sales to NEP as third-party sales in its consolidated financial statements. NEER continues to operate the projects owned by NEP and provide services to NEP under various related party operations and maintenance, administrative and management services agreements. In connection with the deconsolidation, NEE recorded an initial investment in NEP of approximately $4.4 billion based on the fair value of NEP OpCo and NEP common units that were held by subsidiaries of NEE on the deconsolidation date, which investment is included in the investment in equity method investees on NEE's consolidated balance sheets. See Note 8. The fair value was based on the market price of NEP common units as of January 1, 2018, which resulted in NEE recording a gain of approximately $3.9 billion ($3.0 billion after tax) for the year ended December 31, 2018.
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, 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 $725 million, $763 million and $738 million in 2020, 2019 and 2018, 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, 2020 2019 2020 2019 (millions) Regulatory assets: Current: Early retirement of generation facilities $ 36 $ 31 $ 32 $ 27 Acquisition of purchased power agreements 161 165 161 165 Other 180 139 42 35 Total $ 377 $ 335 $ 235 $ 227 Noncurrent: Early retirement of generation facilities $ 1,438 $ 1,004 $ 932 $ 956 Acquisition of purchased power agreements 473 634 473 634 Other 1,801 1,649 991 959 Total $ 3,712 $ 3,287 $ 2,396 $ 2,549 Regulatory liabilities: Current: Deferred clause revenues $ 215 $ 309 $ 197 $ 284 Other 30 11 9 — Total $ 245 $ 320 $ 206 $ 284 Noncurrent: Asset retirement obligation regulatory expense difference $ 3,583 $ 2,826 $ 3,583 $ 2,828 Accrued asset removal costs 1,206 1,346 1,015 1,157 Deferred taxes 4,698 4,862 4,237 4,397 Other 1,248 902 1,217 914 Total $ 10,735 $ 9,936 $ 10,052 $ 9,296 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. At December 31, 2020 and 2019, FPL had regulatory assets, net of amortization, of approximately $634 million and $799 million, respectively, (included in current and noncurrent regulatory assets on NEE's and FPL’s consolidated balance sheets) related to acquisitions during 2015, 2017 and 2018 associated with three coal-fired electric generation facilities located in Florida with which FPL had long-term purchased power agreements. The majority of these regulatory assets are being amortized over approximately nine years. All three facilities have been retired. In 2018, FPL early retired three of its generation facilities. As a result of the retirements, FPL reclassified the net book value of these units (approximately $883 million) from plant in service and other property to current and noncurrent regulatory assets. Recovery of $736 million of these regulatory assets has been deferred until FPL’s base rates are next reset in a general base rate proceeding. The remainder of these regulatory assets are being amortized over 15 years. At December 31, 2020 and 2019, the regulatory assets, net of amortization, totaled approximately $859 million and $851 million, respectively, and are included in current and noncurrent regulatory assets on NEE's and FPL's consolidated balance sheets.
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 (Recovery Act), provided for an option to elect a cash grant (convertible investment tax credits (ITCs)) for certain renewable energy property (renewable property). Convertible ITCs are recorded as a reduction in property, plant and equipment on NEE's and FPL's consolidated balance sheets and are amortized as a reduction to depreciation and amortization expense over the estimated life of the related property. At December 31, 2020 and 2019, convertible ITCs, net of amortization, were approximately $791 million ($122 million at FPL) and $824 million ($128 million at FPL). At December 31, 2020 and 2019, approximately $10 million and $10 million, respectively, of such convertible ITCs are included primarily in other receivables on NEE's consolidated balance sheets. Depreciation of FPL's electric property is provided on a straight-line basis, primarily over its average remaining useful life. FPL includes in depreciation expense a provision for fossil and solar plant dismantlement, interim asset removal costs, accretion related to asset retirement obligations (see Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below), storm recovery amortization and amortization of pre-construction costs associated with planned nuclear units recovered through a cost recovery clause. For substantially all of FPL's property, depreciation studies are typically performed and filed with the FPSC every four years. As part of FPL's 2016 rate agreement, the FPSC approved new depreciation rates which became effective January 1, 2017 and which will remain in effect until FPL's base rates are next reset in a general base rate proceeding. Reserve amortization is recorded as a reduction to (or when reversed as an increase to) accrued asset removal costs which is reflected in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. FPL used available reserve amortization to offset all of the storm restoration costs that were expensed for Hurricane Dorian, Hurricane Isaias and Tropical Storm Eta. 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 fixed targeted regulatory ROE. In order to earn the targeted regulatory ROE in each reporting period under the 2016 rate agreement, reserve amortization is calculated using a trailing thirteen-month average of retail rate base and capital structure in conjunction with the trailing twelve months regulatory retail base net operating income, which primarily includes the retail base portion of base and other revenues, net of O&M, depreciation and amortization, interest and tax expenses. In general, the net impact of these income statement line items is adjusted, in part, by reserve amortization or its reversal to earn the targeted regulatory ROE. NEER's electric plant in service 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% of a utility's plant in service balance and require more than one year to complete. FPSC rules allow construction projects below the 0.5% threshold as a component of rate base. 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, 2020 and 2019, NEER's capitalized development costs totaled approximately $571 million and $651 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, fossil and solar plants over the expected service life of each unit based on nuclear decommissioning and fossil and solar dismantlement studies periodically filed with the FPSC. In addition, FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC. As approved by the FPSC, FPL previously suspended its annual decommissioning accrual. Any differences between expense recognized for financial reporting purposes and the amount recovered through rates are reported as a regulatory liability in accordance with regulatory accounting. See Rate Regulation, Electric Plant, Depreciation and Amortization, and Asset Retirement Obligations above and Note 11. Nuclear decommissioning studies are performed at least every five years and are submitted to the FPSC for approval. FPL filed updated nuclear decommissioning studies with the FPSC in December 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 $7.0 billion, or $2.5 billion expressed in 2020 dollars. 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 2020, 2019 and 2018 fund earnings on decommissioning funds were approximately $132 million, $125 million and $94 million, respectively. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. Fossil and solar plant dismantlement studies are typically performed at least every four years and are submitted to the FPSC for approval. As part of the 2016 rate agreement, the FPSC approved an annual expense of $26 million based on FPL's 2016 fossil and solar dismantlement studies, which became effective January 1, 2017, and is recorded in depreciation and amortization expense in NEE's and FPL's consolidated statements of income, and which will remain in effect until FPL's base rates are next reset in a general base rate proceeding. At December 31, 2020, FPL's portion of the ultimate cost to dismantle its fossil and solar units is approximately $1.2 billion, or $541 million expressed in 2020 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, 2020 and 2019, NEER's ARO was approximately $1,232 million and $1,097 million, respectively, and was primarily determined using various internal and external data and applying a probability percentage to a variety of scenarios regarding the life of the plant and timing of decommissioning or dismantlement. NEER's portion of the ultimate cost of decommissioning its nuclear plants, including costs associated with spent fuel storage above what is expected to be refunded by the DOE under a spent fuel settlement agreement, is estimated to be approximately $9.5 billion, or $2.1 billion expressed in 2020 dollars. The ultimate cost to dismantle NEER's wind and solar facilities is estimated to be approximately $2.4 billion. Seabrook files a comprehensive nuclear decommissioning study with the New Hampshire Nuclear Decommissioning Financing Committee (NDFC) every four years; the most recent study was filed in 2019. Seabrook's decommissioning funding plan is also subject to annual review by the NDFC. Currently, there are no ongoing decommissioning funding requirements for Seabrook, Duane Arnold and Point Beach, however, the U.S. Nuclear Regulatory Commission (NRC), and in the case of Seabrook, the NDFC, has the authority to require additional funding in the future. NEER's portion of Seabrook's, Duane Arnold's and Point Beach's restricted funds for the payment of future expenditures to decommission these plants is included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily carried at fair value. See Note 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 fossil maintenance as incurred. FPL recognizes costs associated with planned major nuclear maintenance in accordance with regulatory treatment. FPL defers nuclear maintenance costs for each nuclear unit’s planned outage to a regulatory asset as the costs are incurred and amortizes the costs to O&M expense over the period from the end of the current outage to the end of the next planned outage.
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, 2020 and 2019, NEE had approximately $441 million ($76 million for FPL) and $508 million ($118 million for FPL), respectively, of restricted cash, of which approximately $374 million ($58 million for FPL) and $411 million ($54 million for FPL), respectively, is included in current other assets and the remaining balance is included in noncurrent other assets on NEE's and FPL's consolidated balance sheets. Restricted cash is primarily related to debt service payments, bond proceeds held for construction at FPL and margin cash collateral requirements. In addition, where offsetting positions exist, restricted cash related to margin cash collateral of $183 million is netted against derivative assets and $136 million is netted against derivative liabilities at December 31, 2020 and $139 million is netted against derivative assets and $66 million is netted against derivative liabilities at December 31, 2019. 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 - 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.
Inventory	Inventory - FPL values materials, supplies and fossil fuel inventory using a weighted-average cost method. NEER's materials, supplies and fossil 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.
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 $27 million, $18 million and $19 million for the years ended December 31, 2020, 2019 and 2018, respectively, and is expected to be approximately $32 million, $17 million, $16 million, $18 million and $17 million for 2021, 2022, 2023, 2024 and 2025, 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 (FASB) issued an accounting standards update which provides certain options to apply GAAP guidance on contract modifications and hedge accounting as companies transition from the London Inter-Bank Offered Rate (LIBOR) and other interbank offered rates to alternative reference rates that are yet to be determined or finalized. NEE’s and FPL’s contracts that reference LIBOR or other interbank offered rates mainly relate to debt and derivative instruments. The standards update was effective upon issuance but can be applied prospectively through December 31, 2022. NEE and FPL are currently evaluating whether to apply the options provided by the standards update with regard to their contracts that reference LIBOR or other interbank offered rates as an interest rate benchmark.
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 $3,949 million ($3,567 million for FPL) and $4,141 million ($3,745 million for FPL) at December 31, 2020 and 2019, 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, 2020 and 2019, FPL’s accumulated deferred ITCs were approximately $729 million and $412 million, respectively, and are included in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. NEE and FPL record a deferred income tax benefit created by the convertible ITCs on the difference between the financial statement and tax bases of renewable property. For NEER, this deferred income tax benefit is recorded in income tax expense in the year that the renewable property is placed in service. For FPL, this deferred income tax benefit is offset by a regulatory liability, which is amortized as a reduction of depreciation expense over the approximate lives of the related renewable property in accordance with the regulatory treatment. At December 31, 2020 and 2019, the net deferred income tax benefits associated with FPL's convertible ITCs were approximately $38 million and $40 million, respectively, and are included in noncurrent regulatory assets and noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. A valuation allowance is recorded to reduce the carrying amounts of deferred tax assets when it is more likely than not that such assets will not be realized. NEE recognizes interest income (expense) related to unrecognized tax benefits (liabilities) in interest income and interest expense, respectively, net of the amount deferred at FPL. At FPL, the offset to accrued interest receivable (payable) on income taxes is classified as a regulatory liability (regulatory asset) which will be amortized to income (expense) over a five-year period upon settlement in accordance with regulatory treatment. All tax positions taken by NEE in its income tax returns that are recognized in the financial statements must satisfy a more-likely-than-not threshold. NEE and its subsidiaries file income tax returns in the U.S. federal jurisdiction and various states, the most significant of which is Florida, and certain foreign jurisdictions. Federal tax liabilities, with the exception of certain refund claims, are effectively settled for all years prior to 2017. State and foreign tax liabilities, which have varied statutes of limitations regarding additional assessments, are generally effectively settled for years prior to 2016. At December 31, 2020, NEE had unrecognized tax benefits of approximately $129 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 facilities, with generating capacity totaling approximately 10,913 MW and 1,377 MW, respectively, at December 31, 2020 , to third-party investors. NEE retains a controlling interest in the entities and therefore presents the Class B member interests as noncontrolling interests. Noncontrolling interests represents the portion of net assets in consolidated entities that are not owned by NEE and are reported as a component of equity in NEE’s consolidated balance sheet. The third-party investors are allocated earnings, tax attributes and cash flows in accordance with the respective limited liability company agreements. Those economics are allocated primarily to the third-party investors until they receive a targeted return (the flip date) and thereafter to NEE. NEE has the right to call the third-party interests at specified amounts if and when the flip date occurs. NEE has determined the allocation of economics between the controlling party and third-party investor should not follow the respective ownership percentages for each wind and solar project but rather the hypothetical liquidation of book value (HLBV) method based on the governing provisions in each respective limited liability company agreement. Under the HLBV method, the amounts of income and loss attributable to the noncontrolling interest reflects changes in the amount the owners would hypothetically receive at each balance sheet date under the respective liquidation provisions, assuming the net assets of these entities were liquidated at the recorded amounts, after taking into account any capital transactions, such as contributions and distributions, between the entities and the owners. At the point in time that the
Redeemable Noncontrolling Interests	Redeemable Noncontrolling Interests - Certain subsidiaries of NextEra Energy Resources sold Class B membership interests in entities that have ownership interests in wind facilities to third-party investors. As specified in the respective limited liability company agreements, if, subject to certain contingencies, certain events occur, including, among others, those that would delay construction or cancel any of the underlying projects, an investor has the option to require NEER to return all or part of its investment. As these potential redemptions were outside of NEER’s control, these balances were classified as redeemable noncontrolling interests on NEE's consolidated balance sheet as of December 31, 2019. During 2020, certain contingencies were resolved resulting in $423 million of the December 31, 2019 balance being reclassified to noncontrolling interests.
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 primarily in current and noncurrent other liabilities
Disposal of a Business/Assets	Disposal of Businesses/Assets - In February 2020, a subsidiary of NextEra Energy Resources completed the sale of its ownership interest in two solar generation facilities located in Spain with a total generating capacity of 99.8 MW, 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. The carrying amounts of the major classes of assets related to the facilities that were classified as held for sale, which are included in current other assets on NEE's consolidated balance sheets, were approximately $440 million at December 31, 2019 and primarily represent property, plant and equipment. Liabilities associated with assets held for sale, which are included in current other liabilities on NEE's consolidated balance sheets, were approximately $647 million at December 31, 2019 and primarily represent long-term debt and interest rate derivatives. In 2019, subsidiaries of NextEra Energy Resources completed the sale of ownership interests in three wind generation facilities and three solar generation facilities, including noncontrolling interests in two of the solar facilities, located in the Midwest and West regions of the U.S. with a total net ownership interest in plant capacity (net generating capacity) of 611 MW to a NEP subsidiary for cash proceeds of approximately $1.0 billion, plus working capital of $12 million. A NEER affiliate will continue to operate the facilities included in the sale. In connection with the sale, a gain of approximately $341 million ($259 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2019, which is included in gains on disposal of businesses/assets - net, and noncontrolling interests of approximately $118 million were recorded on NEE's consolidated balance sheet. In 2018, subsidiaries of NextEra Energy Resources completed the sale of its ownership interests in ten wind generation facilities and one solar generation facility located in the Midwest, South and West regions of the U.S. with a total net generating capacity of 1,388 MW to a subsidiary of NEP for net cash proceeds of approximately $1.3 billion, after transaction costs and working capital adjustments and NEP's assumption of approximately $941 million in existing noncontrolling interests related to differential membership investors. In connection with the sale and the related consolidating state income tax effects, a gain of approximately $36 million ($32 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2018 and is included in gains on disposal of businesses/assets - net. Sale of Noncontrolling Ownership Interests - 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 with an expected in service date in early 2021 to a NEP subsidiary. Total cash proceeds for these two separate transactions totaled approximately $656 million, subject to working capital and other adjustments. NEER will continue to consolidate the projects for accounting purposes, see Note 9 - NEER. A NEER 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. If the solar-plus-storage facility achieves commercial operation by June 2021, the contract liability will be reversed and the sale recognized for accounting purposes. Otherwise, NextEra Energy Resources is required to repurchase the facility for approximately $155 million.
Sale of Noncontrolling Ownership Interests	Sale of Noncontrolling Ownership Interests - 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 with an expected in service date in early 2021 to a NEP subsidiary. Total cash proceeds for these two separate transactions totaled approximately $656 million, subject to working capital and other adjustments. NEER will continue to consolidate the projects for accounting purposes, see Note 9 - NEER. A NEER 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. If the solar-plus-storage facility achieves commercial operation by June 2021, the contract liability will be reversed and the sale recognized for accounting purposes. Otherwise, NextEra Energy Resources is required to repurchase the facility for approximately $155 million.
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 2020, 2019 and 2018, NEE’s revenue from contracts with customers was approximately $17.0 billion ($11.6 billion at FPL), $17.5 billion ($12.1 billion at FPL) and $15.4 billion ($11.8 billion at FPL), respectively. NEE's and FPL's receivables are primarily associated with revenues earned from contracts with customers, as well as derivative and lease transactions at NEER, and consist of both billed and unbilled amounts, which are recorded in customer receivables and other receivables on NEE's and FPL's consolidated balance sheets. Receivables represent unconditional rights to consideration and reflect the differences in timing of revenue recognition and cash collections. For substantially all of NEE's and FPL's receivables, regardless of the type of revenue transaction from which the receivable originated, customer and counterparty credit risk is managed in the same manner and the terms and conditions of payment are similar. FPL - FPL’s revenues are derived primarily from tariff-based sales that result from providing electricity to retail customers in Florida with no defined contractual term. Electricity sales to retail customers account for approximately 90% of FPL’s 2020 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, 2020 and 2019, FPL's unbilled revenues amounted to approximately $392 million and $389 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, 2020, FPL expects to record approximately $415 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 2021 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 2024 and certain power purchase agreements with maturity dates through 2034. As of December 31, 2020, NEER expects to record approximately $825 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 fuel and purchased power cost recovery clause (fuel clause). For NEE's non-rate regulated operations, predominantly NEER, essentially all changes in the derivatives' fair value for power purchases and sales, fuel sales and trading activities are recognized on a net basis in operating revenues; fuel purchases used in the production of electricity are recognized in fuel, purchased power and interchange expense; and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's consolidated statements of income. Settlement gains and losses are included within the line items in the consolidated statements of income to which they relate. Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the consolidated statements of income. For commodity derivatives, NEE believes that, where offsetting positions exist at the same location for the same time, the transactions are considered to have been netted and therefore physical delivery has been deemed not to have occurred for financial reporting purposes. Settlements related to derivative instruments are primarily recognized in net cash provided by operating activities in NEE's and FPL's consolidated statements of cash flows.
Fair Value of Financial Instruments	Fair Value Measurement 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.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities (Policies)	12 Months Ended
	Dec. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives, Policy [Policy Text Block]	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 fuel and purchased power cost recovery clause (fuel clause). For NEE's non-rate regulated operations, predominantly NEER, essentially all changes in the derivatives' fair value for power purchases and sales, fuel sales and trading activities are recognized on a net basis in operating revenues; fuel purchases used in the production of electricity are recognized in fuel, purchased power and interchange expense; and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's consolidated statements of income. Settlement gains and losses are included within the line items in the consolidated statements of income to which they relate. Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the consolidated statements of income. For commodity derivatives, NEE believes that, where offsetting positions exist at the same location for the same time, the transactions are considered to have been netted and therefore physical delivery has been deemed not to have occurred for financial reporting purposes. Settlements related to derivative instruments are primarily recognized in net cash provided by operating activities in NEE's and FPL's consolidated statements of cash flows.
Fair Value of Financial Instruments	Fair Value Measurement 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, 2020
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, 2020 2019 2020 2019 (millions) Regulatory assets: Current: Early retirement of generation facilities $ 36 $ 31 $ 32 $ 27 Acquisition of purchased power agreements 161 165 161 165 Other 180 139 42 35 Total $ 377 $ 335 $ 235 $ 227 Noncurrent: Early retirement of generation facilities $ 1,438 $ 1,004 $ 932 $ 956 Acquisition of purchased power agreements 473 634 473 634 Other 1,801 1,649 991 959 Total $ 3,712 $ 3,287 $ 2,396 $ 2,549 Regulatory liabilities: Current: Deferred clause revenues $ 215 $ 309 $ 197 $ 284 Other 30 11 9 — Total $ 245 $ 320 $ 206 $ 284 Noncurrent: Asset retirement obligation regulatory expense difference $ 3,583 $ 2,826 $ 3,583 $ 2,828 Accrued asset removal costs 1,206 1,346 1,015 1,157 Deferred taxes 4,698 4,862 4,237 4,397 Other 1,248 902 1,217 914 Total $ 10,735 $ 9,936 $ 10,052 $ 9,296
Schedule of Regulatory Liabilities	NEE's and FPL's regulatory assets and liabilities are as follows: NEE FPL December 31, December 31, 2020 2019 2020 2019 (millions) Regulatory assets: Current: Early retirement of generation facilities $ 36 $ 31 $ 32 $ 27 Acquisition of purchased power agreements 161 165 161 165 Other 180 139 42 35 Total $ 377 $ 335 $ 235 $ 227 Noncurrent: Early retirement of generation facilities $ 1,438 $ 1,004 $ 932 $ 956 Acquisition of purchased power agreements 473 634 473 634 Other 1,801 1,649 991 959 Total $ 3,712 $ 3,287 $ 2,396 $ 2,549 Regulatory liabilities: Current: Deferred clause revenues $ 215 $ 309 $ 197 $ 284 Other 30 11 9 — Total $ 245 $ 320 $ 206 $ 284 Noncurrent: Asset retirement obligation regulatory expense difference $ 3,583 $ 2,826 $ 3,583 $ 2,828 Accrued asset removal costs 1,206 1,346 1,015 1,157 Deferred taxes 4,698 4,862 4,237 4,397 Other 1,248 902 1,217 914 Total $ 10,735 $ 9,936 $ 10,052 $ 9,296
Schedule of Goodwill and Other Intangible Assets	NEE's goodwill and other intangible assets are as follows: Weighted- December 31, 2020 2019 (years) (millions) Goodwill (by reporting unit): FPL segment: Florida City Gas $ 292 $ 291 Other 9 9 NEER segment: Rate-regulated transmission (see Note 6 - Trans Bay Cable, LLC) 614 610 Gas infrastructure 487 487 Customer supply and trading 93 93 Generation assets 60 28 Corporate and Other: Gulf Power (see Note 6 - Gulf Power Company) 2,688 2,686 Other 11 — Total goodwill $ 4,254 $ 4,204 Other intangible assets not subject to amortization, primarily land easements $ 135 $ 135 Other intangible assets subject to amortization: Purchased power agreements 14 $ 453 $ 401 Other, primarily transportation contracts and customer lists 17 166 72 Total 619 473 Accumulated amortization (61) (56) Total other intangible assets subject to amortization - net $ 558 $ 417

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2020
Derivative [Line Items]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	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, 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, 2019 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: NEE: Commodity contracts $ 1,229 $ 2,082 $ 1,739 $ (2,700) $ 2,350 Interest rate contracts $ — $ 24 $ 2 $ (17) 9 Foreign currency contracts $ — $ 26 $ — $ 1 27 Total derivative assets $ 2,386 FPL - commodity contracts $ — $ 3 $ 1 $ (1) $ 3 Liabilities: NEE: Commodity contracts $ 1,365 $ 1,446 $ 390 $ (2,625) $ 576 Interest rate contracts $ — $ 598 $ 144 $ (17) 725 Foreign currency contracts $ — $ 38 $ — $ 1 39 Total derivative liabilities $ 1,340 FPL - commodity contracts $ — $ 5 $ 9 $ (1) $ 13 Net fair value by NEE balance sheet line item: Current derivative assets (b) $ 762 Noncurrent derivative assets (c) 1,624 Total derivative assets $ 2,386 Current derivative liabilities (d) $ 344 Current other liabilities (e) 133 Noncurrent derivative liabilities 863 Total derivative liabilities $ 1,340 Net fair value by FPL balance sheet line item: Current other assets $ 3 Current other liabilities $ 12 Noncurrent other liabilities 1 Total derivative liabilities $ 13 ______________________ (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 $2 million in margin cash collateral received from counterparties. (c) Reflects the netting of approximately $139 million in margin cash collateral received from counterparties. (d) Reflects the netting of approximately $66 million in margin cash collateral paid to counterparties. (e) See Note 1 - Disposal of Businesses/Assets. 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 $ 78 $ — $ — $ 78 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 ______________________ (a) Includes restricted cash equivalents of approximately $111 million ($56 million for FPL) in current other assets and $42 million ($17 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 consolidated balance sheet. December 31, 2019 Level 1 Level 2 Level 3 Total (millions) Assets: Cash equivalents and restricted cash equivalents: (a) NEE - equity securities $ 363 $ — $ — $ 363 FPL - equity securities $ 156 $ — $ — $ 156 Special use funds: (b) NEE: Equity securities $ 1,875 $ 2,088 (c) $ — $ 3,963 U.S. Government and municipal bonds $ 567 $ 150 $ — $ 717 Corporate debt securities $ — $ 748 $ — $ 748 Mortgage-backed securities $ — $ 517 $ — $ 517 Other debt securities $ — $ 117 $ — $ 117 FPL: Equity securities $ 596 $ 1,895 (c) $ — $ 2,491 U.S. Government and municipal bonds $ 429 $ 106 $ — $ 535 Corporate debt securities $ — $ 533 $ — $ 533 Mortgage-backed securities $ — $ 395 $ — $ 395 Other debt securities $ — $ 111 $ — $ 111 Other investments: (d) NEE: Equity securities $ 34 $ 12 $ — $ 46 Debt securities $ 82 $ 69 $ — $ 151 ______________________ (a) Includes restricted cash equivalents of approximately $60 million ($54 million for FPL) in current other assets and $64 million ($64 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 consolidated balance sheet.
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, 2020 are as follows: Transaction Type Fair Value at Valuation Significant Range Weighted-average (a) Assets Liabilities (millions) Forward contracts - power $ 792 $ (1) Discounted cash flow Forward price (per MWh) $— — $137 $29 Forward contracts - gas 305 25 Discounted cash flow Forward price (per MMBtu) $1 — $8 $3 Forward contracts - congestion 27 7 Discounted cash flow Forward price (various) $(6) — $30 $— Options - power 35 10 Option models Implied correlations 40% — 84% 55% Implied volatilities 5% — 357% 84% Options - primarily gas 128 131 Option models Implied correlations 40% — 96% 55% Implied volatilities 16% — 310% 36% Full requirements and unit contingent contracts 363 121 Discounted cash flow Forward price (per MWh) $5 — $330 $46 Customer migration rate (b) —% — 122% 2% Forward contracts - other 29 12 Total $ 1,679 $ 305 ______________________ (a) Unobservable inputs were weighted by volume. (b) 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, 2020 2019 2018 NEE FPL NEE FPL NEE FPL (millions) Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year $ 1,207 $ (8) $ 647 $ (36) $ 566 $ — Realized and unrealized gains (losses): Included in earnings (a) 547 — 923 — 35 (1) Included in other comprehensive income (loss) (b) 1 — 5 — 7 — Included in regulatory assets and liabilities 2 2 1 1 (18) (18) Purchases 191 — 141 — 152 (16) Sales (c) 114 — — — — — Settlements (562) 6 (356) 25 28 (2) Issuances (123) — (87) — (115) — Impact of adoption of revenue standard — — — — (30) — Transfers in (d) 18 (1) (5) — — — Transfers out (d) (21) — (62) 2 22 1 Fair value of net derivatives based on significant unobservable inputs at December 31 $ 1,374 $ (1) $ 1,207 $ (8) $ 647 $ (36) Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date (e) $ 317 $ — $ 611 $ — $ 100 $ (1) ______________________ (a) For the years ended December 31, 2020, 2019 and 2018, realized and unrealized gains of approximately $569 million, $956 million and $48 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. (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, 2020 2019 2018 (millions) Commodity contracts: (a) Operating revenues $ 352 $ 762 $ 377 Fuel, purchased power and interchange — — (2) Foreign currency contracts - interest expense 8 (7) 19 Interest rate contracts - interest expense (421) (699) (280) Losses reclassified from AOCI: Interest rate contracts (b) (35) (32) (30) Foreign currency contracts - interest expense (3) (4) (4) Total $ (99) $ 20 $ 80 ______________________ (a) For the years ended December 31, 2020, 2019 and 2018, FPL recorded gains (losses) of approximately $6 million, $9 million and $(31) million, respectively, related to commodity contracts as regulatory liabilities (assets) on its consolidated balance sheets.
Net notional volumes	NEE and FPL had derivative commodity contracts for the following net notional volumes: December 31, 2020 December 31, 2019 Commodity Type NEE FPL NEE FPL (millions) Power (90) MWh (a) — (81) MWh (a) 1 MWh (a) Natural gas (607) MMBtu (b) 87 MMBtu (b) (1,723) MMBtu (b) 161 MMBtu (b) Oil (6) barrels — (13) barrels — ______________________ (a) Megawatt-hours (b) One million British thermal units

Non-Derivative Fair Value Mea_2

Non-Derivative Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2020
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, 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, 2019 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: NEE: Commodity contracts $ 1,229 $ 2,082 $ 1,739 $ (2,700) $ 2,350 Interest rate contracts $ — $ 24 $ 2 $ (17) 9 Foreign currency contracts $ — $ 26 $ — $ 1 27 Total derivative assets $ 2,386 FPL - commodity contracts $ — $ 3 $ 1 $ (1) $ 3 Liabilities: NEE: Commodity contracts $ 1,365 $ 1,446 $ 390 $ (2,625) $ 576 Interest rate contracts $ — $ 598 $ 144 $ (17) 725 Foreign currency contracts $ — $ 38 $ — $ 1 39 Total derivative liabilities $ 1,340 FPL - commodity contracts $ — $ 5 $ 9 $ (1) $ 13 Net fair value by NEE balance sheet line item: Current derivative assets (b) $ 762 Noncurrent derivative assets (c) 1,624 Total derivative assets $ 2,386 Current derivative liabilities (d) $ 344 Current other liabilities (e) 133 Noncurrent derivative liabilities 863 Total derivative liabilities $ 1,340 Net fair value by FPL balance sheet line item: Current other assets $ 3 Current other liabilities $ 12 Noncurrent other liabilities 1 Total derivative liabilities $ 13 ______________________ (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 $2 million in margin cash collateral received from counterparties. (c) Reflects the netting of approximately $139 million in margin cash collateral received from counterparties. (d) Reflects the netting of approximately $66 million in margin cash collateral paid to counterparties. (e) See Note 1 - Disposal of Businesses/Assets. 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 $ 78 $ — $ — $ 78 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 ______________________ (a) Includes restricted cash equivalents of approximately $111 million ($56 million for FPL) in current other assets and $42 million ($17 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 consolidated balance sheet. December 31, 2019 Level 1 Level 2 Level 3 Total (millions) Assets: Cash equivalents and restricted cash equivalents: (a) NEE - equity securities $ 363 $ — $ — $ 363 FPL - equity securities $ 156 $ — $ — $ 156 Special use funds: (b) NEE: Equity securities $ 1,875 $ 2,088 (c) $ — $ 3,963 U.S. Government and municipal bonds $ 567 $ 150 $ — $ 717 Corporate debt securities $ — $ 748 $ — $ 748 Mortgage-backed securities $ — $ 517 $ — $ 517 Other debt securities $ — $ 117 $ — $ 117 FPL: Equity securities $ 596 $ 1,895 (c) $ — $ 2,491 U.S. Government and municipal bonds $ 429 $ 106 $ — $ 535 Corporate debt securities $ — $ 533 $ — $ 533 Mortgage-backed securities $ — $ 395 $ — $ 395 Other debt securities $ — $ 111 $ — $ 111 Other investments: (d) NEE: Equity securities $ 34 $ 12 $ — $ 46 Debt securities $ 82 $ 69 $ — $ 151 ______________________ (a) Includes restricted cash equivalents of approximately $60 million ($54 million for FPL) in current other assets and $64 million ($64 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 consolidated balance sheet.
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, 2020 December 31, 2019 Carrying Estimated Carrying Estimated (millions) NEE: Special use funds (a) $ 919 $ 920 $ 892 $ 891 Other investments (b) $ 29 $ 29 $ 30 $ 30 Long-term debt, including current portion $ 46,082 $ 51,525 (c) $ 39,667 (d) $ 42,928 (c)(d) FPL: Special use funds (a) $ 718 $ 719 $ 706 $ 705 Long-term debt, including current portion $ 15,676 $ 19,470 (c) $ 14,161 $ 16,448 (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, 2020 and 2019, substantially all is Level 2 for NEE and all is Level 2 for FPL. (d) Excludes debt totaling approximately $463 million classified as held for sale, which is included in current other liabilities on NEE's consolidated balance sheet at December 31, 2019, for which the carrying amount approximates fair value. See Note 1 - Disposal of Businesses/Assets.
Unrealized Gains (Losses) Recognized On Equity Securities	Unrealized gains (losses) recognized on equity securities held at December 31, 2020 and 2019 are as follows: NEE FPL Years Ended December 31, Years Ended December 31, 2020 2019 2020 2019 (millions) Unrealized gains (losses) $ 627 $ 780 $ 444 $ 510
Available-for-sale Securities	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, 2020 2019 2018 2020 2019 2018 (millions) Realized gains $ 110 $ 68 $ 51 $ 83 $ 44 $ 31 Realized losses $ 70 $ 48 $ 75 $ 56 $ 29 $ 49 Proceeds from sale or maturity of securities $ 2,541 $ 3,005 $ 2,551 $ 2,162 $ 2,539 $ 2,100 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, 2020 2019 2020 2019 (millions) Unrealized gains $ 134 $ 75 $ 104 $ 58 Unrealized losses (a) $ 9 $ 7 $ 9 $ 7 Fair value $ 201 $ 314 $ 150 $ 240 ______________________ (a) Unrealized losses on available for sale debt securities in an unrealized loss position for greater than twelve months at December 31, 2020 and 2019 were not material to NEE or FPL.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020 2019 2018 2020 2019 2018 (millions) Federal: Current $ 105 $ 167 $ 30 $ 53 $ 348 $ 251 Deferred (148) 115 1,153 388 (29) 134 Total federal (43) 282 1,183 441 319 385 State: Current 18 23 63 44 49 91 Deferred 69 143 330 125 73 63 Total state 87 166 393 169 122 154 Total income taxes $ 44 $ 448 $ 1,576 $ 610 $ 441 $ 539
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, 2020 2019 2018 2020 2019 2018 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) 2.8 3.4 4.2 4.1 3.5 4.5 Taxes attributable to noncontrolling interests 4.8 2.1 2.5 — — — PTCs and ITCs - NEER (11.8) (7.2) (3.0) — — — Amortization of deferred regulatory credit (b) (7.2) (6.2) (1.8) (5.0) (8.1) (5.0) Foreign operations (c) (2.4) — (0.8) — — — Other - net (5.4) (1.4) (0.7) (1.4) (0.5) (0.6) Effective income tax rate 1.8 % 11.7 % 21.4 % 18.7 % 15.9 % 19.9 % _________________________ (a) 2019 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 tax reform. 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).
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, 2020 2019 2020 2019 (millions) Deferred tax liabilities: Property-related $ 10,065 $ 10,133 $ 6,791 $ 6,394 Pension 437 417 394 374 Investments in partnerships and joint ventures 2,238 2,019 3 — Other 1,730 1,618 672 685 Total deferred tax liabilities 14,470 14,187 7,860 7,453 Deferred tax assets and valuation allowance: Decommissioning reserves 290 317 290 286 Net operating loss carryforwards 299 380 2 2 Tax credit carryforwards 3,859 3,406 — — ARO and accrued asset removal costs 347 368 226 273 Regulatory liabilities 1,380 1,335 1,259 1,219 Other 755 515 293 258 Valuation allowance (a) (289) (285) — — Net deferred tax assets 6,641 6,036 2,070 2,038 Net deferred income taxes $ 7,829 $ 8,151 $ 5,790 $ 5,415 ______________________ (a) Reflects valuation allowances related to deferred state tax credits and state operating loss carryforwards, and, in 2019, also reflects valuation allowances related to the solar projects in Spain that completely offset the related deferred taxes. Deferred tax assets and liabilities are included on the consolidated balance sheets as follows: NEE FPL December 31, December 31, 2020 2019 2020 2019 (millions) Noncurrent other assets $ 191 $ 210 $ — $ — Deferred income taxes - noncurrent liabilities (8,020) (8,361) (5,790) (5,415) Net deferred income taxes $ (7,829) $ (8,151) $ (5,790) $ (5,415)
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, 2020 are as follows: Amount Expiration (millions) Net operating loss carryforwards: Federal $ 2 2033-2037 State 280 2021-2040 Foreign 17 2021-2040 Net operating loss carryforwards $ 299 Tax credit carryforwards: Federal $ 3,508 2029-2040 State 348 (a) 2021-2045 Foreign 3 2034-2040 Tax credit carryforwards $ 3,859 ______________________ (a) Includes $191 million of ITC carryforwards with an indefinite expiration period.

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2020
Jointly-Owned Electric Plants [Abstract]
Proportionate Ownership Interest In Jointly-Owned Facilities	NEE's and FPL's proportionate ownership interest in jointly-owned facilities is as follows: December 31, 2020 Ownership Gross Investment (a) Accumulated Depreciation (a) Construction (millions) FPL: St. Lucie Unit No. 2 85 % $ 2,260 $ 999 $ 47 Scherer Unit No. 4 (b) 76 % $ 1,300 $ 502 $ 2 Gulf Power: Daniel Units Nos. 1 and 2 50 % $ 718 $ 241 $ 39 Scherer Unit No. 3 25 % $ 445 $ 168 $ 2 NEER: (c) Seabrook 88.23 % $ 1,290 $ 412 $ 53 Wyman Station Unit No. 4 91.19 % $ 30 $ 9 $ 1 Stanton 65 % $ 138 $ 13 $ — Transmission substation assets located in Seabrook, New Hampshire 88.23 % $ 114 $ 9 $ 11 ______________________ (a) Excludes nuclear fuel. (b) Together with its joint interest owner, and subject to certain approvals from the FPSC, FPL intends to retire this unit in early 2022. (c) NEER also owns an approximately 70% interest in Duane Arnold, a nuclear facility that ceased operations in August 2020.

Investments in Partnerships a_2

Investments in Partnerships and Joint Ventures (Tables)	12 Months Ended
	Dec. 31, 2020
Investments in Partnerships and Joint Ventures [Abstract]
Summarized combined information for principal operating entities	Summarized combined information for these principal entities is as follows: 2020 2019 (millions) Net income $ 516 $ 128 Total assets $ 22,717 $ 20,659 Total liabilities $ 6,612 $ 6,956 Partners'/members' equity (a) $ 16,105 $ 13,703 NEE's share of underlying equity in the principal entities $ 3,927 $ 3,723 Difference between investment carrying amount and underlying equity in net assets (b) 1,312 3,153 NEE's investment carrying amount for the principal entities $ 5,239 $ 6,876 ______________________ (a) Reflects NEE's interest, as well as third-party interests, in NEP OpCo. (b) Approximately $2.8 billion in 2020 and $3.0 billion in 2019 is associated with NEP OpCo; of which approximately 70% relates to goodwill and is not being amortized; the remaining balance is being amortized primarily over a period of 20 to 28 years. The 2020 difference is net of an approximately $1.5 billion impairment charge related to NextEra Energy Resources' investment in Mountain Valley Pipeline.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2018 $ 3,135 $ 2,147 Liabilities incurred 100 1 Accretion expense 172 107 Liabilities settled (65) (a) (1) Revision in estimated cash flows - net 32 (b) 14 (b) Additions from acquisitions 132 (c) — Balances, December 31, 2019 3,506 (d) 2,268 (d) Liabilities incurred 138 — Accretion expense 169 100 Liabilities settled (53) (6) Revision in estimated cash flows - net (594) (e) (558) (e) Balances, December 31, 2020 $ 3,166 (d) $ 1,804 (d) ______________________ (a) Primarily reflects sales of ownership interests to subsidiaries of NEP. See Note 1 - Disposal of Businesses/Assets. (b) Includes an increase of approximately $75 million for additional estimated ash pond closure costs at Scherer, partly offset by a decrease of approximately $71 million due to the approval of Turkey Point Units Nos. 3 and 4 license renewals for an additional 20 years. (c) See Note 6 for 2019 acquisitions. (d) Includes the current portion of AROs as of December 31, 2020 and 2019 of approximately $109 million ($21 million for FPL) and $49 million (none for FPL), respectively, which is included in other current liabilities on NEE's and FPL's consolidated balance sheets. (e) 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.
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, 2020 $ 7,703 $ 5,271 Balances, December 31, 2019 $ 6,880 $ 4,697

Employee Retirement Benefits (T

Employee Retirement Benefits (Tables)	12 Months Ended
	Dec. 31, 2020
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: 2020 2019 (millions) Change in pension plan assets: Fair value of plan assets at January 1 $ 4,800 $ 3,806 Actual return on plan assets 723 736 Benefit payments (209) (235) Acquisitions (a) — 493 Fair value of plan assets at December 31 $ 5,314 $ 4,800 Change in pension benefit obligation: Obligation at January 1 $ 3,363 $ 2,522 Service cost 85 80 Interest cost 92 114 Acquisitions (a) — 503 Special termination benefits (b) 16 19 Plan amendments 1 3 Actuarial losses - net (c) 259 357 Benefit payments (209) (235) Obligation at December 31 (d) $ 3,607 $ 3,363 Funded status: Prepaid pension benefit costs at NEE at December 31 $ 1,707 $ 1,437 Prepaid pension benefit costs at FPL at December 31 (e) $ 1,554 $ 1,477 _________________________ (a) Relates to substantially funded pension obligations in connection with the acquisition of Gulf Power, see Note 6 - Gulf Power Company. (b) Reflects enhanced early retirement programs. (c) Primarily driven by decrease in discount rates. (d) NEE's accumulated pension benefit obligation, which includes no assumption about future salary levels, at December 31, 2020 and 2019 was approximately $3,521 million and $3,281 million, respectively. (e) 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: 2020 2019 (millions) Unrecognized prior service benefit (net of $1 and $2 tax expense, respectively) $ 2 $ 2 Unrecognized losses (net of $24 and $37 tax benefit, respectively) (60) (108) Total $ (58) $ (106)
Unrecognized amounts included in regulatory assets (liabilities)	NEE's unrecognized amounts included in regulatory assets yet to be recognized as components of net prepaid pension benefit costs are as follows: 2020 2019 (millions) Unrecognized prior service benefit $ (1) $ (2) Unrecognized losses 163 263 Total $ 162 $ 261
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. 2020 2019 Discount rate (a) 2.53 % 3.22 % Salary increase 4.40 % 4.40 % Weighted-average interest crediting rate 3.82 % 3.83 % _________________________ (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: 2020 2019 2018 Discount rate 3.22 % 4.26 % 3.59 % Salary increase 4.40 % 4.40 % 4.10 % Expected long-term rate of return, net of investment management fees (a) 7.35 % 7.35 % 7.35 % Weighted-average interest crediting rate 3.83 % 3.88 % 3.94 % ______________________ (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, 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. December 31, 2019 (a) Quoted Prices Significant Significant Total (millions) Equity securities (b) $ 1,593 $ 9 $ 3 $ 1,605 Equity commingled vehicles (c) — 706 — 706 U.S. Government and municipal bonds 95 7 — 102 Corporate debt securities (d) — 247 — 247 Asset-backed securities — 416 — 416 Debt security commingled vehicles (e) 47 143 — 190 Convertible securities (f) 32 372 — 404 Total investments in the fair value hierarchy $ 1,767 $ 1,900 $ 3 3,670 Total investments measured at net asset value (g) 1,130 Total fair value of plan assets $ 4,800 ______________________ (a) See Notes 3 and 4 for discussion of fair value measurement techniques and inputs. (b) Includes foreign investments of $741 million. (c) Includes foreign investments of $141 million. (d) Includes foreign investments of $76 million. (e) Includes foreign investments of $5 million. (f) Includes foreign investments of $20 million. (g) Includes foreign investments of $190 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): 2021 $ 228 2022 $ 200 2023 $ 202 2024 $ 204 2025 $ 206 2026 - 2030 $ 1,024
Net periodic benefit (income) cost	Net Periodic Income - The components of net periodic income for the plans are as follows: Pension Benefits Postretirement Benefits 2020 2019 2018 2020 2019 2018 (millions) Service cost $ 85 $ 80 $ 70 $ 1 $ 1 $ 1 Interest cost 92 114 82 8 9 7 Expected return on plan assets (321) (312) (276) — — — Amortization of actuarial loss 18 — — 3 — — Amortization of prior service benefit (1) (1) (1) (16) (15) (15) Special termination benefits 16 19 35 — — — Net periodic income at NEE $ (111) $ (100) $ (90) $ (4) $ (5) $ (7) Net periodic income allocated to FPL $ (77) $ (71) $ (57) $ (3) $ (4) $ (6)
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: 2020 2019 2018 (millions) Net gains (losses) (net of $13 tax expense, $10 tax benefit and $4 tax benefit, respectively) $ 42 $ (36) $ (13) Amortization of unrecognized losses (net of $1 tax expense) 5 — — Total $ 47 $ (36) $ (13)
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: 2020 2019 (millions) Prior service cost $ 1 $ — Unrecognized gains (89) (113) Amortization of prior service cost 1 $ 1 Amortization of unrecognized losses (12) — Total $ (99) $ (112)

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2020
Debt Disclosure [Abstract]
Debt Issuances and Borrowings by Subsidiaries	Long-term debt consists of the following: December 31, 2020 2019 Maturity Balance Weighted- Balance Weighted- (millions) (millions) FPL: (a) First mortgage bonds - fixed 2023-2049 $ 13,090 4.32 % $ 12,005 4.46 % Pollution control, solid waste disposal and industrial development revenue bonds - primarily variable (b) 2021-2049 948 0.12 % 1,076 1.67 % Senior unsecured notes - variable (c)(d) 2023-2070 1,806 0.44 % 1,236 2.18 % Unamortized debt issuance costs and discount (168) (156) Total long-term debt of FPL 15,676 14,161 Less current portion of long-term debt 54 30 Long-term debt of FPL, excluding current portion 15,622 14,131 GULF POWER: (a) Senior unsecured notes - fixed 2022-2044 815 4.05 % 990 4.17 % Other long-term debt - primarily variable (b) 2021-2050 759 0.70 % 709 1.93 % Unamortized debt issuance costs and discount (14) (14) Total long-term debt of Gulf Power 1,560 1,685 Less current portion of long-term debt 300 175 Long-term debt of Gulf Power, excluding current portion 1,260 1,510 NEER: NextEra Energy Resources: Senior secured limited-recourse long-term debt - primarily variable (d)(e) 2024-2049 3,325 2.33 % 3,419 3.79 % Other long-term debt - primarily variable (d)(e) 2024-2040 450 2.72 % 440 (f) 3.78 % NEET - long-term debt - primarily fixed (e) 2021-2049 937 3.09 % 837 3.50 % Unamortized debt issuance costs and premium (65) (74) Total long-term debt of NEER 4,647 4,622 Less current portion of long-term debt 239 215 Long-term debt of NEER, excluding current portion 4,408 4,407 NEECH: Debentures - fixed (e) 2021-2030 11,540 2.86 % 9,550 3.05 % Debentures - variable (d) 2021-2022 1,225 0.80 % 1,375 3.00 % Debentures, related to NEE's equity units - fixed 2024-2025 6,000 1.46 % 1,500 2.10 % Junior subordinated debentures - primarily fixed (e) 2057-2079 3,693 4.78 % 4,643 5.13 % Japanese yen denominated long-term debt - primarily variable (d)(e)(g) 2023-2030 650 1.49 % 645 3.10 % Australian dollar denominated long-term debt - fixed (g) 2026 385 2.20 % 351 2.59 % Other long-term debt - fixed 2021 221 0.92 % 524 2.00 % Other long-term debt - variable (d) 2021 600 0.70 % 750 2.60 % Unamortized debt issuance costs, premium and discount (115) (139) Total long-term debt of NEECH 24,199 19,199 Less current portion of long-term debt 3,545 1,704 Long-term debt of NEECH, excluding current portion 20,654 17,495 Total long-term debt $ 41,944 $ 37,543 ______________________ (a) See Note 6 - Merger of FPL and Gulf Power regarding FPL's assumption of all of Gulf Power's outstanding debt on January 1, 2021. (b) 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 or Gulf Power, as the case may be, would be required to purchase the variable rate tax exempt bonds. At December 31, 2020, variable rate tax exempt bonds totaled approximately $948 million at FPL and $426 million at Gulf Power. All variable rate tax exempt bonds tendered for purchase have been successfully remarketed. FPL's and Gulf Power's syndicated revolving credit facilities, as the case may be, 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. Gulf Power's remaining debt is primarily variable which is based on an underlying index plus a margin. (c) Includes approximately $556 million of floating rate notes that permit individual noteholders to require repayment prior to maturity. FPL’s syndicated revolving credit facilities are available to support the purchase of the senior unsecured notes. (d) Variable rate is based on an underlying index plus a specified margin. (e) Interest rate contracts, primarily swaps, have been entered into with respect to certain of these debt issuances. See Note 3. (f) Excludes approximately $463 million classified as held for sale, which is included in current other liabilities on NEE's consolidated balance sheets. See Note 1 - Disposal of Businesses/Assets. (g) Foreign currency contracts have been entered into with respect to these debt issuances. See Note 3.

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020 2019 2018 (millions, except per share amounts) Numerator: Net income attributable to NEE - basic $ 2,919 $ 3,769 $ 6,638 Adjustment for the impact of dilutive securities at NEP (a) — — (19) Net income attributable to NEE - assuming dilution $ 2,919 $ 3,769 $ 6,619 Denominator: Weighted-average number of common shares outstanding - basic 1,959.0 1,927.9 1,892.8 Equity units, stock options, performance share awards and restricted stock (b) 9.8 14.0 15.1 Weighted-average number of common shares outstanding - assuming dilution 1,968.8 1,941.9 1,907.9 Earnings per share attributable to NEE: Basic $ 1.49 $ 1.95 $ 3.51 Assuming dilution $ 1.48 $ 1.94 $ 3.47 _________ _____________ (a) The 2018 adjustment is related to both the NEP Series A convertible preferred units and the NEP senior unsecured convertible notes issued in 2017 (see Potentially Dilutive Securities at NEP below). (b) 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, 2020 was as follows: Shares Weighted- Restricted Stock: Nonvested balance, January 1, 2020 1,980,592 $ 39.93 Granted 631,186 $ 68.25 Vested (870,780) $ 39.58 Forfeited (66,756) $ 49.21 Nonvested balance, December 31, 2020 1,674,242 $ 50.26 Performance Share Awards: Nonvested balance, January 1, 2020 2,680,584 $ 35.61 Granted 1,535,436 $ 46.09 Vested (2,081,264) $ 32.93 Forfeited (196,148) $ 44.85 Nonvested balance, December 31, 2020 1,938,608 $ 47.46
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: 2020 2019 2018 Expected volatility (a) 14.63 – 16.31% 14.20 - 14.31% 14.41% Expected dividends 2.50 – 2.72% 2.85 - 2.93% 3.05% Expected term (years) (b) 7.0 7.0 7.0 Risk-free rate 0.49 – 1.52% 2.24 - 2.54% 2.83% ______________________ (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, 2020 was as follows: Shares Weighted- Weighted- Aggregate Balance, January 1, 2020 9,666,752 $ 30.77 Granted 1,519,712 $ 68.76 Exercised (1,513,324) $ 64.53 Forfeited (54,936) $ 59.18 Balance, December 31, 2020 9,618,204 $ 38.32 6.2 $ 373 Exercisable, December 31, 2020 6,382,356 $ 29.69 5.1 $ 303
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, 2017 $ (77) $ 316 $ (39) $ (69) $ (20) $ 111 Other comprehensive income (loss) before reclassifications — (12) (14) (31) 4 (53) Amounts reclassified from AOCI 26 (a) 1 (b) (3) (c) — — 24 Net other comprehensive income (loss) 26 (11) (17) (31) 4 (29) Impact of NEP deconsolidation (d) 3 — — 37 18 58 Adoption of accounting standards updates (7) (312) (9) — — (328) 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 (e) — — (13) (e) — 10 Balances, December 31, 2020 $ 8 $ 20 $ (75) $ (49) $ 4 $ (92) Attributable to noncontrolling interests $ — $ — $ — $ (8) $ — $ (8) Attributable to NEE $ 8 $ 20 $ (75) $ (41) $ 4 $ (84) ———————————— (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 and included in gain on NEP deconsolidation. See Note 1 - Basis of Presentation. (e) 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.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Schedule of Planned Capital Expenditures	At December 31, 2020, estimated capital expenditures for 2021 through 2025 for which applicable internal approvals (and also, if required, regulatory approvals such as FPSC approvals for FPL and Gulf Power) have been received were as follows: 2021 2022 2023 2024 2025 Total (millions) FPL: Generation: (a) New (b) $ 780 $ 880 $ 680 $ 540 $ 530 $ 3,410 Existing 1,085 1,155 1,045 1,010 750 5,045 Transmission and distribution (c) 4,065 3,665 3,825 4,290 4,490 20,335 Nuclear fuel 220 170 120 145 145 800 General and other 740 760 810 725 780 3,815 Total $ 6,890 $ 6,630 $ 6,480 $ 6,710 $ 6,695 $ 33,405 Gulf Power $ 860 $ 695 $ 625 $ 685 $ 685 $ 3,550 NEER: Wind (d) $ 1,770 $ 60 $ 15 $ 15 $ 5 $ 1,865 Solar (e) 1,565 340 185 — — 2,090 Battery storage 355 — — — — 355 Nuclear, including nuclear fuel 230 190 145 190 200 955 Natural gas pipelines (f) 285 165 — — — 450 Rate-regulated transmission 205 25 10 15 30 285 Other 730 125 100 75 60 1,090 Total $ 5,140 $ 905 $ 455 $ 295 $ 295 $ 7,090 ______________________ (a) Includes AFUDC of approximately $75 million, $50 million, $25 million, $15 million and $15 million for 2021 through 2025, respectively. (b) Includes land, generation structures, transmission interconnection and integration and licensing. (c) Includes AFUDC of approximately $50 million, $50 million, $40 million, $55 million and $45 million for 2021 through 2025, respectively. (d) Consists of capital expenditures for new wind projects, repowering of existing wind projects and related transmission totaling approximately 2,394 MW. (e) Includes capital expenditures for new solar projects and related transmission totaling approximately 2,354 MW. (f) Construction of natural gas pipelines are subject to certain conditions, including applicable regulatory approvals and in certain cases the resolution of legal challenges.
Required Capacity and/or Minimum Payments	The required capacity and/or minimum payments under contracts, including those discussed above at December 31, 2020, were estimated as follows: 2021 2022 2023 2024 2025 Thereafter (millions) FPL (a) $ 1,030 $ 970 $ 950 $ 940 $ 890 $ 9,380 NEER (b)(c)(d) $ 3,250 $ 530 $ 210 $ 210 $ 140 $ 1,635 _______________________ (a) Includes approximately $415 million, $415 million, $410 million, $410 million, $405 million and $6,360 million in 2021 through 2025 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 $386 million, $316 million and $303 million for the years ended December 31, 2020, 2019 and 2018, respectively, of which $108 million, $108 million and $95 million, respectively, were eliminated in consolidation at NEE. (b) Includes approximately $25 million, $70 million, $70 million, $70 million and $1,155 million for 2022 through 2025 and thereafter, respectively, of firm commitments related to a natural gas transportation agreement with a joint venture, in which NEER has a 31.5% equity investment, that is constructing a natural gas pipeline. These firm commitments are subject to the completion of construction of the pipeline which is currently estimated to be in 2022. (c) Includes approximately $85 million of commitments to invest in technology investments through 2029. (d) Includes approximately $480 million, $20 million, $20 million, $10 million, $10 million and $5 million for 2021 through 2025 and thereafter, respectively, of joint obligations of NEECH and NEER.

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2020
Segment Reporting [Abstract]
Segment Information	NEE's segment information is as follows: 2020 FPL Gulf Power (a) NEER (b) 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 Interest income $ 2 $ 2 $ 28 $ 6 $ 38 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) (c) $ 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 2019 FPL Gulf Power (a) NEER (b) Corp. and NEE (millions) Operating revenues $ 12,192 $ 1,487 $ 5,639 $ (114) $ 19,204 Operating expenses - net (d) $ 8,895 $ 1,216 $ 4,037 $ 109 $ 14,257 Gains (losses) on disposal of businesses/assets - net (d) $ 5 $ — $ 402 $ (1) $ 406 Interest expense $ 594 $ 55 $ 873 $ 727 $ 2,249 Interest income $ 5 $ 3 $ 38 $ 8 $ 54 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) (c) $ 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) See Note 6 - Gulf Power Company and - Merger of FPL and Gulf Power. (b) 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. (c) NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 - Income Taxes. (d) FPL's income statement line for total operating expenses - net includes gains (losses) on disposal of businesses/assets - net. 2018 FPL NEER (a)(b) Corp. and NEE (millions) Operating revenues $ 11,862 $ 4,984 $ (119) $ 16,727 Operating expenses - net (c) $ 8,714 $ 3,698 $ 115 $ 12,527 Gains (losses) on disposal of businesses/assets - net (c) $ 6 $ 82 $ (8) $ 80 Interest expense $ 541 $ 595 $ 362 $ 1,498 Interest income $ 4 $ 40 $ 7 $ 51 Depreciation and amortization $ 2,633 $ 1,230 $ 48 $ 3,911 Equity in earnings of equity method investees $ — $ 321 $ 37 $ 358 Income tax expense (benefit) (d) $ 539 $ 1,196 $ (159) $ 1,576 Net income (loss) $ 2,171 $ 3,842 $ (237) $ 5,776 Net income (loss) attributable to NEE $ 2,171 $ 4,704 $ (237) $ 6,638 Capital expenditures, independent power and other investments and nuclear fuel purchases $ 5,135 $ 7,189 $ 680 $ 13,004 Property, plant and equipment - net $ 41,499 $ 28,602 $ 233 $ 70,334 Total assets $ 53,484 $ 44,509 $ 5,709 $ 103,702 Investment in equity method investees $ — $ 6,521 $ 227 $ 6,748 _________________________ (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) NEP was deconsolidated from NEER in January 2018. See Note 1 - Basis of Presentation. (c) FPL's income statement line for total operating expenses - net includes gains (losses) on disposal of businesses/assets - net. (d) NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 - Income Taxes.

Quarterly Data (Unaudited) (Tab

Quarterly Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2020
Quarterly Data (Unaudited) [Abstract]
Condensed Consolidated Quarterly Financial Information	in the following table has been retrospectively adjusted to reflect the 2020 stock split. See Note 14 - Earnings Per Share. March 31 June 30 September 30 December 31 2020 Earnings per share attributable to NEE - basic (a) $ 0.21 $ 0.65 $ 0.63 $ — Earnings per share attributable to NEE - assuming dilution (a) $ 0.21 $ 0.65 $ 0.62 $ — Dividends per share $ 0.35 $ 0.35 $ 0.35 $ 0.35 High-low common stock sales prices $70.84 - $43.70 $65.56 - $53.26 $74.82 - $59.58 $83.34 - $69.63 2019 Earnings per share attributable to NEE - basic (a) $ 0.36 $ 0.64 $ 0.46 $ 0.50 Earnings per share attributable to NEE - assuming dilution (a) $ 0.35 $ 0.64 $ 0.45 $ 0.50 Dividends per share $ 0.3125 $ 0.3125 $ 0.3125 $ 0.3125 High-low common stock sales prices $48.89 - $42.17 $52.23 - $46.82 $58.36 - $50.27 $61.25 - $55.17 ______________________ (a) The sum of the quarterly amounts may not equal the total for the year due to rounding and changes in weighted-average number of common shares outstanding.

Summary of Significant Accoun_4

Summary of Significant Accounting and Reporting Policies (Additional Information) (Details) € in Millions, account in Millions	Jan. 01, 2023USD ($)	Oct. 26, 2020	Sep. 14, 2020	Feb. 11, 2020USD ($)solar_generation_facilityMW	Apr. 01, 2019USD ($)MW	Jan. 01, 2018USD ($)	Jan. 01, 2017USD ($)	Jan. 31, 2022USD ($)	Sep. 30, 2020USD ($)customer	Dec. 31, 2025USD ($)MW	Dec. 31, 2024USD ($)MW	Dec. 31, 2020USD ($)facilityaccountcountyunitMW	Dec. 31, 2019USD ($)solar_generation_facilitywind_generation_facilityMW	Dec. 31, 2018USD ($)facilitywind_generation_facilitysolar_generation_facilityMW	Dec. 31, 2020USD ($)kWhcountyfacilityaccountMW	Feb. 11, 2020EUR (€)	Jan. 01, 2020USD ($)
Basis of Presentation [Abstract]
Number of customer accounts (more than) | account												5.6			5.6
Number of counties In which entity operates | county												8			8
Stockholders' Equity Note, Stock Split, Conversion Ratio		4	4
Noncontrolling Interest [Abstract]
Investment in equity method investees												$ 5,728,000,000	$ 7,453,000,000	$ 6,748,000,000	$ 5,728,000,000
Equity Method Investment, Realized Gain (Loss) on Deconsolidation, Before Tax														3,900,000,000
Equity Method Investment, Realized Gain (Loss) on Deconsolidation, After Tax														3,000,000,000
Regulated and Unregulated Operating Revenue [Abstract]
Revenue from contracts with customers												17,000,000,000	17,500,000,000	15,400,000,000
Electric Plant, Depreciation and Amortization [Abstract]
Convertible ITCs												791,000,000	824,000,000
Convertible ITCs included in other receivables												10,000,000	10,000,000		10,000,000
Construction Activity [Abstract]
Impairment charges													72,000,000
Impairment of long-lived assets, after tax													54,000,000
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Asset Retirement Obligation												3,166,000,000	3,506,000,000	3,135,000,000	3,166,000,000
Restricted Cash [Abstract]
restricted cash related to margin cash collateral that is netted against derivative assets												183,000,000	139,000,000		183,000,000
restricted cash related to margin cash collateral that is netted against derivative liabilities												136,000,000	(66,000,000)		136,000,000
Restricted cash												441,000,000	508,000,000		441,000,000
Measurement of Credit Losses on Financial Instruments [Abstract]
Retained earnings												25,363,000,000	25,199,000,000		25,363,000,000
Income Taxes [Abstract]
Revenue equivalent of the difference in accumulated deferred income taxes computed under accounting rules, as compared to regulatory accounting rules												$ 3,949,000,000	4,141,000,000		3,949,000,000
Amortization period												5 years
Unrecognized tax benefits that impact annual effective income tax rate												$ 129,000,000			$ 129,000,000
Variable Interest Entities [Abstract]
Net Income (Loss) Attributable to Noncontrolling Interest												$ (550,000,000)	(381,000,000)	(862,000,000)
Redeemable noncontrolling interests													$ 423,000,000
Leases [Abstract]
Operating Lease, Liability, Statement of Financial Position [Extensible List]												us-gaap:OtherLiabilities	us-gaap:OtherLiabilities		us-gaap:OtherLiabilities
Disposal of a Business/Assets [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal												$ 353,000,000	$ 406,000,000	80,000,000
Sale of Noncontrolling Ownership Interests [Abstract]
Proceeds from Sale of Interest in Partnership Unit												$ 656,000,000
Solar Generating Capacity | MW												100			100
Solar Plus Storage Facility Capacity | MW												30			30
Customer deposits												$ 474,000,000	499,000,000		$ 474,000,000
Purchaser Of Facility Terms Not Met												155,000,000			155,000,000
Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Abstract]
Income (Loss) Attributable to Noncontrolling Interest, before Tax												497,000,000
Net Income (Loss) Attributable to Noncontrolling Interest												373,000,000
Accounting Standards Update 2016-13 [Member]
Measurement of Credit Losses on Financial Instruments [Abstract]
Retained earnings																	$ 11,000,000
FPL[Member]
Regulated and Unregulated Operating Revenue [Abstract]
Revenue from contracts with customers												11,600,000,000	12,100,000,000	$ 11,800,000,000
Regulated Operations [Abstract]
Number of generation facilities retired during period | facility														3
Net book value												$ 48,933,000,000	45,074,000,000		$ 48,933,000,000
FPSC rate orders and 2021 Base Rate Proceeding [Abstract]
Increase in base rate revenues					$ 200,000,000	$ 211,000,000	$ 400,000,000
Energy Assets, Power Generation Capacity | MW					1,720
Renewable energy assets, power generation capacity (mw) | MW												1,200			1,200
Regulatory return on common equity (in hundredths)															10.55%
Earned regulatory ROE threshold below which retail base rate relief may be sought (in hundredths)															9.60%
Earned regulatory ROE threshold above which retail base rate reduction may be sought (in hundredths)															11.60%
Time period after filing of a cost recovery petition that future storm restoration costs would be recoverable on an interim basis															60 days
Maximum Amount Of Depreciation Reserve That May Be Amortized															$ 1,000,000,000
Reserve amount remaining under 2012 rate agreement that may be amortized															250,000,000
Maximum Storm Surcharge															4
Threshold Of Storm Restoration Costs In Any Given Calendar Year At Which Surcharge May Be Increased															800,000,000
Threshold Of Storm Restoration Costs In Any Given Calendar Year At Which Surcharge May Be Increased, Amount Above Which May Be Recovered															$ 400,000,000
Increment Of Usage In Kwh On Which Storm Surcharge Is Based | kWh															1,000
Cost Of Recovery Period															12 months
Electric Plant, Depreciation and Amortization [Abstract]
Convertible ITCs												$ 122,000,000	128,000,000
Maximum interval between depreciation studies performed and filed with the FPSC (in years)												four years
Construction Activity [Abstract]
Threshold of plant in service balance at which AFUDC may be recorded (in hundredths)												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												$ 7,000,000,000			$ 7,000,000,000
FPL's Ultimate costs of nuclear decommissioning, in current year dollars												2,500,000,000			2,500,000,000
FPL's fund earnings on decommissioning funds												$ 132,000,000	125,000,000	$ 94,000,000
Maximum interval between plant dismantlement studies submitted to the FPSC for approval (in years)												4 years
Plant Dismantlement Approved Expense Effective January 2017												$ 26,000,000
Ultimate Costs Of Plant Dismantlement												1,200,000,000			1,200,000,000
Ultimate Costs Of Plant Dismantlement In Current Year Dollars												541,000,000			541,000,000
Asset Retirement Obligation												1,804,000,000	2,268,000,000	$ 2,147,000,000	1,804,000,000
Restricted Cash [Abstract]
Restricted cash												76,000,000	118,000,000		76,000,000
Measurement of Credit Losses on Financial Instruments [Abstract]
Retained earnings												9,614,000,000	9,174,000,000		9,614,000,000
Income Taxes [Abstract]
Revenue equivalent of the difference in accumulated deferred income taxes computed under accounting rules, as compared to regulatory accounting rules												3,567,000,000	3,745,000,000		3,567,000,000
Accumulated Deferred Investment Tax Credit												729,000,000	412,000,000		729,000,000
Deferred income tax benefit associated with convertible ITCs												38,000,000	40,000,000
Sale of Noncontrolling Ownership Interests [Abstract]
Customer deposits												430,000,000	459,000,000		430,000,000
FPL[Member] | Hurricane Dorian [Member]
Storm Funds Storm Reserves and Storm Cost Recovery Abstract
Storm restoration costs													239,000,000
FPL[Member] | Hurricane Isaias and Tropical Storm Eta [Member]
Storm Funds Storm Reserves and Storm Cost Recovery Abstract
Storm restoration costs												200,000,000			200,000,000
NEER [Member]
Noncontrolling Interest [Abstract]
Investment in equity method investees												5,239,000,000	6,876,000,000		5,239,000,000
Construction Activity [Abstract]
Project development costs of NextEra Energy Resources												$ 571,000,000	$ 651,000,000		$ 571,000,000
Deemed capital structure of NextEra Energy Resources (in hundredths)												70.00%			70.00%
Wind Electric Generating Facility Capability | MW													220
Impairment charges												$ 1,500,000,000
Impairment of long-lived assets, after tax												1,200,000,000
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Asset Retirement Obligation												1,232,000,000	$ 1,097,000,000		$ 1,232,000,000
Ultimate Costs Of Nuclear Decommissioning For Wholly Owned Indirect Subsidiary												9,500,000,000			9,500,000,000
Ultimate Costs Of Nuclear Decommissioning In Current Year Dollars For Wholly Owned Indirect Subsidiary												2,100,000,000			2,100,000,000
Ultimate costs to dismantle wind and solar facilities												$ 2,400,000,000
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												10,913
Variable Interest Entities [Abstract]
Wind Electric Generating Facility Capability | MW												10,913
Solar generating facility capability | MW												1,377
Gulf Power [Member]
Regulated Operations [Abstract]
Regulatory Assets, Coal Generating Assets												$ 462,000,000			$ 462,000,000
Gulf Power [Member] | Hurricane Sally [Member]
Storm Funds Storm Reserves and Storm Cost Recovery Abstract
Eligible storm restoration costs									$ 206,000,000
Public Utilities, Number Of Customers Impacted By Hurricane | customer									285,000
subsidiary of NextEra Energy Resources [Member]
Disposal of a Business/Assets [Abstract]
Total generating facility capacity (mw) | MW												900
Sale of Noncontrolling Ownership Interests [Abstract]
Number Of Wind Generation Facilities | facility												3			3
Number Solar Generation Facilities | facility												4			4
Reduction To Additional Paid In Capital, Gross												$ 188,000,000			$ 188,000,000
Reduction To Additional Paid In Capital, Net												165,000,000			165,000,000
Other Noncontrolling Interests												689,000,000			689,000,000
Customer deposits												$ 155,000,000			$ 155,000,000
subsidiary of NextEra Energy Resources [Member] | Third Party [Member]
Sale of Noncontrolling Ownership Interests [Abstract]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners												50.00%			50.00%
subsidiary of NextEra Energy Resources [Member] | subsidiary of NextEra Energy Resources [Member]
Sale of Noncontrolling Ownership Interests [Abstract]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners												90.00%			90.00%
subsidiary of NextEra Energy Resources [Member] | NEP [Member]
Sale of Noncontrolling Ownership Interests [Abstract]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners												40.00%			40.00%
subsidiary of NextEra Energy Resources [Member] | Solar-Plus-Storage Facility [Member]
Sale of Noncontrolling Ownership Interests [Abstract]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners												100.00%			100.00%
Forecast [Member] | FPL[Member]
FPSC rate orders and 2021 Base Rate Proceeding [Abstract]
Increase in base rate revenues	$ 615,000,000							$ 1,100,000,000
Renewable energy assets, power generation capacity (mw) | MW										900	900
Regulatory return on common equity (in hundredths)								11.50%
Base Rate Plan Term								4 years
Base Rate Adjustments										$ 140,000,000	$ 140,000,000
Basis Point Incentive								0.50%
Minimum [Member] | FPL[Member]
FPSC rate orders and 2021 Base Rate Proceeding [Abstract]
Regulatory return on common equity (in hundredths)															9.60%
Maximum [Member] | FPL[Member]
FPSC rate orders and 2021 Base Rate Proceeding [Abstract]
Regulatory return on common equity (in hundredths)															11.60%
Coal Fired Generation Facility [Member]
Regulated Operations [Abstract]
Regulatory assets, net of amortization												$ 634,000,000	$ 799,000,000		$ 634,000,000
Coal Fired Generation Facility [Member] | FPL[Member]
Regulated Operations [Abstract]
Regulatory assets, net of amortization												634,000,000	799,000,000		634,000,000
Number of coal-fired electric generation facilities | facility														3
Regulatory asset, amortization period														9 years
Current other assets [Member]
Restricted Cash [Abstract]
Restricted cash, current												374,000,000	411,000,000		374,000,000
Current other assets [Member] | FPL[Member]
Restricted Cash [Abstract]
Restricted cash, current												58,000,000	54,000,000		58,000,000
NEP [Member]
Noncontrolling Interest [Abstract]
Investment in equity method investees													4,400,000,000
Franchise and Gross Receipts Taxes [Member]
Regulated and Unregulated Operating Revenue [Abstract]
Revenue from contracts with customers												725,000,000	763,000,000	$ 738,000,000
Franchise and Gross Receipts Taxes [Member] | FPL[Member]
Regulated and Unregulated Operating Revenue [Abstract]
Revenue from contracts with customers												725,000,000	763,000,000	738,000,000
Retired Plant [Member]
Regulated Operations [Abstract]
Regulatory assets, net of amortization												859,000,000	851,000,000		859,000,000
Retired Plant [Member] | FPL[Member]
Regulated Operations [Abstract]
Regulatory assets, net of amortization												859,000,000	851,000,000		$ 859,000,000
Net book value														883,000,000
Amount of regulatory assets deferred														$ 736,000,000
Regulatory asset, amortization period														15 years
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Two solar generation facilities located in Spain [Member]
Disposal of a Business/Assets [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal												270,000,000
Disposal Group, Not Discontinued Operation, Gain (Loss) On Disposal, Net Of Tax												$ 270,000,000
Disposal Group, Including Discontinued Operation, Other Assets, Current													440,000,000
Current other liabilities													647,000,000
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 [Abstract]
Number Of Generation Facilities Sold | solar_generation_facility				2
Total generating facility capacity (mw) | MW				99.8
Disposal Group, Including Discontinued Operation, Consideration				$ 121,000,000												€ 111
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 [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal													341,000,000
Disposal Group, Not Discontinued Operation, Gain (Loss) On Disposal, Net Of Tax													259,000,000
Disposal Group, Including Discontinued Operation, Stockholders' Equity Attributable to Noncontrolling Interest													$ 118,000,000
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 [Abstract]
Total generating facility capacity (mw) | MW													611
Disposal Group, Including Discontinued Operation, Consideration													$ 1,000,000,000
Disposal Group, Including Discontinued Operation, Working Capital													$ 12,000,000
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Solar plants [Member] | NEER [Member]
Disposal of a Business/Assets [Abstract]
Number Of Generation Facilities Sold | solar_generation_facility													3	1
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Solar plants [Member] | Noncontrolling Interest [Member] | NEER [Member]
Disposal of a Business/Assets [Abstract]
Number Of Generation Facilities Sold | solar_generation_facility													2
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | ten wind generation facilities and one solar generation facility [Member] | NEER [Member]
Disposal of a Business/Assets [Abstract]
Total generating facility capacity (mw) | MW														1,388
Disposal Group, Including Discontinued Operation, Consideration														$ 1,300,000,000
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal														36,000,000
Disposal Group, Not Discontinued Operation, Gain (Loss) On Disposal, Net Of Tax														32,000,000
Assumption Of Noncontrolling Interest														$ 941,000,000
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Wind plants [Member] | NEER [Member]
Disposal of a Business/Assets [Abstract]
Number Of Generation Facilities Sold | wind_generation_facility													3	10

Summary of Significant Accoun_5

Summary of Significant Accounting and Reporting Policies (Regulatory Assets and Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Current:
Early retirement of generation facilities	$ 36	$ 31
Acquisition of purchased power agreements	161	165
Other	180	139
Total	377	335
Noncurrent:
Early retirement of generation facilities	1,438	1,004
Acquisition of purchased power agreements	473	634
Other	1,801	1,649
Total	3,712	3,287
Current:
Deferred clause revenues	215	309
Other	30	11
Total	245	320
Noncurrent:
Asset retirement obligation regulatory expense difference	3,583	2,826
Accrued asset removal costs	1,206	1,346
Deferred taxes	4,698	4,862
Other	1,248	902
Total	10,735	9,936
FPL[Member]
Current:
Early retirement of generation facilities	32	27
Acquisition of purchased power agreements	161	165
Other	42	35
Total	235	227
Noncurrent:
Early retirement of generation facilities	932	956
Acquisition of purchased power agreements	473	634
Other	991	959
Total	2,396	2,549
Current:
Deferred clause revenues	197	284
Other	9	0
Total	206	284
Noncurrent:
Asset retirement obligation regulatory expense difference	3,583	2,828
Accrued asset removal costs	1,015	1,157
Deferred taxes	4,237	4,397
Other	1,217	914
Total	$ 10,052	$ 9,296

Summary of Significant Accoun_6

Summary of Significant Accounting and Reporting Policies (Goodwill and Intangible Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Goodwill and Intangible Assets [Line Items]
Goodwill	$ 4,254	$ 4,204
Other intangible assets not subject to amortization, primarily land easements	135	135
Other intangible assets:
Total	619	473
Accumulated amortization	(61)	(56)
Total other intangible assets subject to amortization - net	558	417
Intangible assets, amortization [Abstract]
Amortization expense	27	18	$ 19
Amortization Expense 2021	32
Amortization Expense 2022	17
Amortization Expense 2023	16
Amortization Expense 2024	18
Amortization Expense 2025	$ 17
Purchased Power Agreements [Member]
Other intangible assets:
Weighted average useful lives (years)	14 years
Total	$ 453	401
Other, primarily transmission and development rights and customer lists [Member]
Other intangible assets:
Weighted average useful lives (years)	17 years
Total	$ 166	72
Rate-Regulated Transmission [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	614	610
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	93	93
Generation Assets [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	60	28
Other Goodwill Assets [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	11	0
FPL[Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	301	300
FPL[Member] | Florida City Gas [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	292	291
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	$ 2,686

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 17,000	$ 17,500	$ 15,400
Unbilled revenues	$ 392	389
FPL [Member] | Revenue Benchmark [Member]
Disaggregation of Revenue [Line Items]
Concentration risk, percentage	90.00%
NEER [Member]
Disaggregation of Revenue [Line Items]
Revenue, remaining performance obligation	$ 825
FPL[Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	11,600	12,100	$ 11,800
Unbilled revenues	392	$ 389
Revenue, remaining performance obligation	$ 415

Derivative Instruments (Details

Derivative Instruments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ (7)
Derivative, Collateral, Obligation to Return Cash	6	$ 10
Margin Cash Collateral Not Netted Against Derivative Liabilities	315	360
Reclassification from AOCI, Current Period, before Tax, Attributable to Parent	26	11	$ 3
Reclassification from AOCI, Current Period, Net of Tax, Attributable to Parent	6	$ 8	$ 2
FPL[Member]
Derivative [Line Items]
Derivative, Collateral, Obligation to Return Cash	0
Margin Cash Collateral Not Netted Against Derivative Liabilities	0
Interest Rate Contract [Member] | 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

Derivative Instruments (Balance

Derivative Instruments (Balance Sheet Disclosure) (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Current	$ 570	$ 762
Derivative Asset, Noncurrent	1,647	1,624
Derivative Assets	2,217	2,386
Derivative Liability, Current	311	344
Derivative Liability, Noncurrent	1,199	863
Derivative Liabilities	1,510	1,340
Current derivative assets [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Margin cash collateral received from counterparties		2
Non Current Derivative Assets Member [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Margin cash collateral received from counterparties	184	139
Other Current Liabilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Current other liabilities		133
Current derivative liabilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Margin cash collateral paid to counterparties	136	66
Commodity contracts [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets	2,154	2,350
Derivative Liabilities	500	576
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	(2,325)	(2,700)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	(2,277)	(2,625)
Commodity contracts [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	919	1,229
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	1,004	1,365
Commodity contracts [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	1,881	2,082
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	1,468	1,446
Commodity contracts [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	1,679	1,739
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	305	390
Interest Rate Contract [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets	40	9
Derivative Liabilities	1,001	725
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	(41)	(17)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	(41)	(17)
Interest Rate Contract [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	0	0
Interest Rate Contract [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	81	24
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	1,042	598
Interest Rate Contract [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0	2
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	0	144
Currency Swap [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets	23	27
Derivative Liabilities	9	39
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	(34)	1
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	(34)	1
Currency Swap [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	0	0
Currency Swap [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	57	26
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	43	38
Currency Swap [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	0	0
FPL[Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Liabilities	3	13
FPL[Member] | Current other assets [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Current	3	3
FPL[Member] | Other Current Liabilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Liability, Current	2	12
FPL[Member] | Other Noncurrent Liabilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Liability, Noncurrent	1
Derivative Liabilities		1
FPL[Member] | Commodity contracts [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets	3	3
Derivative Liabilities	3	13
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	0	(1)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	0	(1)
FPL[Member] | Commodity contracts [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0	0
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	0	0
FPL[Member] | Commodity contracts [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	1	3
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	0	5
FPL[Member] | Commodity contracts [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	2	1
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	$ 3	$ 9

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Significant Unobservable Inputs) (Details) - Significant Unobservable Inputs (Level 3) [Member]	12 Months Ended
	Dec. 31, 2020USD ($)
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	$ 1,679,000,000
Liabilities, Fair Value Disclosure	305,000,000
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	137
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	0
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	29
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	792,000,000
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	8
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	1
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	$ 305,000,000
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	84.00%
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	40.00%
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	55.00%
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	357.00%
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	5.00%
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	84.00%
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	$ 35,000,000
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	96.00%
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	40.00%
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	55.00%
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	310.00%
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	16.00%
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	$ 128,000,000
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	330
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	5
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	$ 46
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	122.00%
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	$ 363,000,000
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	29,000,000
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	27,000,000
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	30
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	(6)
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	(1,000,000)
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	25,000,000
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	10,000,000
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	131,000,000
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	121,000,000
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	12,000,000
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	$ 7,000,000

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities (Reconciliation of Changes in the Fair Value) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
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	$ 1,207	$ 647	$ 566
Realized and unrealized gains (losses):
Included in earnings	547	923	35
Included in other comprehensive income (loss)	1	5	7
Included in regulatory assets and liabilities	2	1	(18)
Purchases	191	141	152
Sales	114	0	0
Settlements	(562)	(356)	28
Issuances	(123)	(87)	(115)
Impact of adoption of new revenue standard	0	0	(30)
Transfers in	18	(5)	0
Transfers out	(21)	(62)	22
Fair value of net derivatives based on significant unobservable inputs at December 31	1,374	1,207	647
Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date	317	611	100
Realized and unrealized gains (losses) reflected in operating revenues	569	956	48
Unrealized gains (losses) reflected in operating revenues, for derivatives still held at the reporting date	317	638	112
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	(8)	(36)	0
Realized and unrealized gains (losses):
Included in earnings	0	0	(1)
Included in other comprehensive income (loss)	0	0	0
Included in regulatory assets and liabilities	2	1	(18)
Purchases	0	0	(16)
Sales	0	0	0
Settlements	6	25	(2)
Issuances	0	0	0
Impact of adoption of new revenue standard	0	0	0
Transfers in	(1)	0	0
Transfers out	0	2	1
Fair value of net derivatives based on significant unobservable inputs at December 31	(1)	(8)	(36)
Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date	0	$ 0	$ (1)
Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Liabilities, Fair Value Disclosure	$ 305

Derivative Instruments (Income

Derivative Instruments (Income Statement Disclosure) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	$ (99)	$ 20	$ 80
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal	353	406	80
Not Designated as Hedging Instrument [Member] | Commodity contracts [Member] | 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	352	762	377
Not Designated as Hedging Instrument [Member] | Commodity contracts [Member] | Gains (Losses) Included In Fuel, Purchased Power And Interchange [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	0	0	(2)
Not Designated as Hedging Instrument [Member] | Foreign currency contracts [Member] | 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	8	(7)	19
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | 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	(421)	(699)	(280)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Not Designated as Hedging Instrument [Member] | Foreign currency contracts [Member] | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Interest Expense	(3)	(4)	(4)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Interest Expense	(35)	(32)	(30)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Gains (Loss) On Disposal Of Businesses/Assets - Net [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal	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	$ 6	$ 9	$ (31)

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, 2020USD ($)MWhMMBTUbbl	Dec. 31, 2019USD ($)MWhMMBTUbbl
Interest Rate Swap [Member]
Derivative [Line Items]
Derivative, Notional Amount | $	$ 10.5	$ 8.9
Currency Swap [Member]
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	90	81
Short [Member] | Commodity contract - Natural gas [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	607	1,723
Short [Member] | Commodity contract - Oil [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount, Volume | bbl	6	13
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	1
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	87	161

Derivative Instruments (Credit

Derivative Instruments (Credit Risk Disclosures) (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Derivative [Line Items]
Liability position of derivative	$ 1,900	$ 1,700
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Bbb Or Baa2	80	215
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Below Investment Grade	1,200	1,200
Additional Collateral Aggregate Fair Value Due To Other Financial Measures	880	590
Collateral Already Posted, Aggregate Fair Value	2	2
Letters Of Credit Already Posted Aggregate Fair Value	66	88
FPL[Member]
Derivative [Line Items]
Liability position of derivative	3	12
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	75	35
Additional Collateral Aggregate Fair Value Due To Other Financial Measures	75	75
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) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Assets [Abstract]
Restricted cash	$ 441	$ 508
Derivatives [Abstract]
Derivative Assets	2,217	2,386
Derivatives [Abstract]
Derivative Liabilities	1,510	1,340
Fair Value, Recurring [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	742	363
Special use funds [Abstract]
Equity securities	4,726	3,963
U.S. Government and municipal bonds	717	717
Corporate debt securities	871	748
Mortgage-backed securities	422	517
Other debt securities	124	117
Other Investments [Abstract]
Equity securities	62	46
Debt securities	218	151
Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	742	363
Special use funds [Abstract]
Equity securities	2,237	1,875
U.S. Government and municipal bonds	590	567
Corporate debt securities	1	0
Mortgage-backed securities	0	0
Other debt securities	0	0
Other Investments [Abstract]
Equity securities	62	34
Debt securities	91	82
Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member] | Current other assets [Member]
Assets [Abstract]
Restricted cash	111	60
Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member] | Other Noncurrent Assets [Member]
Assets [Abstract]
Restricted cash	42	64
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	0	0
Special use funds [Abstract]
Equity securities	2,489	2,088
U.S. Government and municipal bonds	127	150
Corporate debt securities	870	748
Mortgage-backed securities	422	517
Other debt securities	124	117
Other Investments [Abstract]
Equity securities	0	12
Debt securities	127	69
Significant Unobservable Inputs (Level 3) [Member] | Fair Value, Recurring [Member]
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	0	0
Commodity contracts [Member] | Fair Value, Recurring [Member]
Derivatives [Abstract]
Asset offsetting	2,325	2,700
Derivative Assets	2,154	2,350
Derivatives [Abstract]
Liability offsetting	2,277	2,625
Derivative Liabilities	500	576
Commodity contracts [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member]
Other Investments [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	919	1,229
Derivatives [Abstract]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	1,004	1,365
Commodity contracts [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Other Investments [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	1,881	2,082
Derivatives [Abstract]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	1,468	1,446
Commodity contracts [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fair Value, Recurring [Member]
Other Investments [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	1,679	1,739
Derivatives [Abstract]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	305	390
Interest Rate Contract [Member] | Fair Value, Recurring [Member]
Derivatives [Abstract]
Asset offsetting	41	17
Derivative Assets	40	9
Derivatives [Abstract]
Liability offsetting	41	17
Derivative Liabilities	1,001	725
Interest Rate Contract [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member]
Other Investments [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0	0
Derivatives [Abstract]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	0	0
Interest Rate Contract [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Other Investments [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	81	24
Derivatives [Abstract]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	1,042	598
Interest Rate Contract [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fair Value, Recurring [Member]
Other Investments [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0	2
Derivatives [Abstract]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	0	144
Currency Swap [Member] | Fair Value, Recurring [Member]
Derivatives [Abstract]
Asset offsetting	34	(1)
Derivative Assets	23	27
Derivatives [Abstract]
Liability offsetting	34	(1)
Derivative Liabilities	9	39
Currency Swap [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member]
Other Investments [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0	0
Derivatives [Abstract]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	0	0
Currency Swap [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Other Investments [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	57	26
Derivatives [Abstract]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	43	38
Currency Swap [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fair Value, Recurring [Member]
Other Investments [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0	0
Derivatives [Abstract]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	0	0
FPL[Member]
Assets [Abstract]
Restricted cash	76	118
Derivatives [Abstract]
Derivative Liabilities	3	13
FPL[Member] | Fair Value, Recurring [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	78	156
Special use funds [Abstract]
Equity securities	3,012	2,491
U.S. Government and municipal bonds	536	535
Corporate debt securities	627	533
Mortgage-backed securities	335	395
Other debt securities	119	111
FPL[Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	78	156
Special use funds [Abstract]
Equity securities	752	596
U.S. Government and municipal bonds	449	429
Corporate debt securities	0	0
Mortgage-backed securities	0	0
Other debt securities	0	0
FPL[Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member] | Current other assets [Member]
Assets [Abstract]
Restricted cash	56	54
FPL[Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member] | Other Noncurrent Assets [Member]
Assets [Abstract]
Restricted cash	17	64
FPL[Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	0	0
Special use funds [Abstract]
Equity securities	2,260	1,895
U.S. Government and municipal bonds	87	106
Corporate debt securities	627	533
Mortgage-backed securities	335	395
Other debt securities	119	111
FPL[Member] | Significant Unobservable Inputs (Level 3) [Member] | Fair Value, Recurring [Member]
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
FPL[Member] | Commodity contracts [Member] | Fair Value, Recurring [Member]
Derivatives [Abstract]
Asset offsetting	0	1
Derivative Assets	3	3
Derivatives [Abstract]
Liability offsetting	0	1
Derivative Liabilities	3	13
FPL[Member] | Commodity contracts [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Fair Value, Recurring [Member]
Other Investments [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0	0
Derivatives [Abstract]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	0	0
FPL[Member] | Commodity contracts [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Other Investments [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	1	3
Derivatives [Abstract]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	0	5
FPL[Member] | Commodity contracts [Member] | Significant Unobservable Inputs (Level 3) [Member] | Fair Value, Recurring [Member]
Other Investments [Abstract]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	2	1
Derivatives [Abstract]
Derivative Liability, Fair Value, Gross Liability Including Not Subject to Master Netting Arrangement	$ 3	$ 9

Non-Derivative Fair Value Mea_4

Non-Derivative Fair Value Measurements (Nonrecurring Fair Value Measurements) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets, carrying amount	$ 91,803	$ 82,010	$ 70,334
Impairment of long-lived assets		72
Impairment of long-lived assets, after tax		$ 54
NEER [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

Non-Derivative Fair Value Mea_5

Non-Derivative Fair Value Measurements (Fair Value of Instruments Recorded at Other than Fair Value) (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Reported Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	$ 919	$ 892
Other Investments Financial Instruments Fair Value Disclosure	29	30
Long Term Debt Including Current Maturities Fair Value Disclosure	46,082	39,667
Reported Value Measurement [Member] | Other Current Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long Term Debt Including Current Maturities Fair Value Disclosure	463
Estimate of Fair Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	920	891
Other Investments Financial Instruments Fair Value Disclosure	29	30
Long Term Debt Including Current Maturities Fair Value Disclosure	51,525	42,928
FPL[Member] | Reported Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	718	706
Long Term Debt Including Current Maturities Fair Value Disclosure	15,676	14,161
FPL[Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	719	705
Long Term Debt Including Current Maturities Fair Value Disclosure	$ 19,470	$ 16,448

Non-Derivative Fair Value Mea_6

Non-Derivative Fair Value Measurements (Gains and Losses) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Schedule of Available-for-sale Securities[Line Items]
Decommissioning Fund Investments, Fair Value	$ 7,703	$ 6,880
Special Use Funds Storm Fund Assets	76	74
Debt Securities, Available-for-sale, Amortized Cost	$ 2,009	2,030
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	$ 110	68	$ 51
Realized losses	70	48	75
Proceeds from sale and maturity of Available-for-sale Securities	2,541	3,005	2,551
Available for sale securities: Special Use Funds - Debt Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
Unrealized gains	134	75
Unrealized losses	9	7
Fair Value	201	314
FPL[Member]
Schedule of Available-for-sale Securities[Line Items]
Decommissioning Fund Investments, Fair Value	5,271	4,697
Special Use Funds Storm Fund Assets	76	74
Debt Securities, Available-for-sale, Amortized Cost	$ 1,521	1,523
Special Use Funds Nuclear Decommissioning Funds Weighted Average Maturity	9 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	$ 83	44	31
Realized losses	56	29	49
Proceeds from sale and maturity of Available-for-sale Securities	2,162	2,539	$ 2,100
FPL[Member] | Available for sale securities: Special Use Funds - Debt Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
Unrealized gains	104	58
Unrealized losses	9	7
Fair Value	$ 150	240
Debt Securities [Member] | FPL[Member] | Storm Fund [Member]
Schedule of Available-for-sale Securities[Line Items]
Debt Securities, Available-for-sale, Term	1 year
Equity Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
marketable securities, unrealized gain (loss) recognized during the period on securities still held	$ 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	$ 444	$ 510
Weighted Average [Member] | Nuclear Decommissioning Funds [Member]
Schedule of Available-for-sale Securities[Line Items]
Debt Securities, Available-for-sale, Term
Weighted Average [Member] | FPL[Member] | Nuclear Decommissioning Funds [Member]
Schedule of Available-for-sale Securities[Line Items]
Debt Securities, Available-for-sale, Term
Weighted Average [Member] | FPL[Member] | Storm Fund [Member]
Schedule of Available-for-sale Securities[Line Items]
Debt Securities, Available-for-sale, Term	1 year

Income Taxes - Components of In

Income Taxes - Components of Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Federal:
Current	$ 105	$ 167	$ 30
Deferred	(148)	115	1,153
Total federal	(43)	282	1,183
State:
Current	18	23	63
Deferred	69	143	330
Total state	87	166	393
Total income taxes	44	448	1,576
FPL[Member]
Federal:
Current	53	348	251
Deferred	388	(29)	134
Total federal	441	319	385
State:
Current	44	49	91
Deferred	125	73	63
Total state	169	122	154
Total income taxes	$ 610	$ 441	$ 539

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Effective Income Tax Rate (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
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)	2.80%	3.40%	4.20%
Taxes attributable to noncontrolling interests	4.80%	2.10%	2.50%
PTCs and ITCs - NEER	(11.80%)	(7.20%)	(3.00%)
Amortization of deferred regulatory credit(b)	7.20%	6.20%	(1.80%)
Foreign operations(c)			(0.80%)
Other - net	(5.40%)	(1.40%)	(0.70%)
Effective income tax rate (in hundredths)	1.80%	11.70%	21.40%
Effective Income Tax Rate Reconciliation, Foreign Income Tax Rate Differential, Percent	(2.40%)	0.00%
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%	3.50%	4.50%
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)	5.00%	8.10%	(5.00%)
Foreign operations(c)			0.00%
Other - net	(1.40%)	(0.50%)	(0.60%)
Effective income tax rate (in hundredths)	18.70%	15.90%	19.90%
Amortization of deferred regulatory credit		$ 83
Amortization Of Excess Deferred Income Taxes		$ 870
Effective Income Tax Rate Reconciliation, Foreign Income Tax Rate Differential, Percent	0.00%	0.00%

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Deferred tax liabilities:
Property-related	$ 10,065	$ 10,133
Pension	437	417
Investments in partnerships and joint ventures	2,238	2,019
Other	1,730	1,618
Total deferred tax liabilities	14,470	14,187
Deferred tax assets and valuation allowance:
Decommissioning reserves	290	317
Net operating loss carryforwards	299	380
Tax credit carryforwards	3,859	3,406
ARO and accrued asset removal costs	347	368
Regulatory liabilities	1,380	1,335
Other	755	515
Valuation allowance	(289)	(285)
Net deferred tax assets	6,641	6,036
Net deferred income taxes	7,829	8,151
Deferred tax assets and liabilities included in the consolidated balance sheets [Abstract]
Noncurrent other assets	191	210
Deferred income taxes - noncurrent liabilities	(8,020)	(8,361)
Net deferred income taxes	(7,829)	(8,151)
FPL[Member]
Deferred tax liabilities:
Property-related	6,791	6,394
Pension	394	374
Investments in partnerships and joint ventures	3	0
Other	672	685
Total deferred tax liabilities	7,860	7,453
Deferred tax assets and valuation allowance:
Decommissioning reserves	290	286
Net operating loss carryforwards	2	2
Tax credit carryforwards	0	0
ARO and accrued asset removal costs	226	273
Regulatory liabilities	1,259	1,219
Other	293	258
Valuation allowance	0	0
Net deferred tax assets	2,070	2,038
Net deferred income taxes	5,790	5,415
Deferred tax assets and liabilities included in the consolidated balance sheets [Abstract]
Noncurrent other assets	0	0
Deferred income taxes - noncurrent liabilities	(5,790)	(5,415)
Net deferred income taxes	$ (5,790)	$ (5,415)

Income Taxes - Tax Carryforward

Income Taxes - Tax Carryforwards and Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	$ 299	$ 380
Tax credit carryforwards	3,859	$ 3,406
Federal [Member]
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	2
Tax credit carryforwards	3,508
State [Member]
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	280
Tax credit carryforwards	348
Tax credit carryforward with indefinite expiration period	191
Foreign [Member]
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	17
Tax credit carryforwards	$ 3

Acquisitions (Details)

Acquisitions (Details) $ in Millions	Sep. 29, 2020USD ($)stateutlitymi	Jul. 16, 2019USD ($)mi	Jan. 01, 2019USD ($)customercountymiMW	Dec. 31, 2018USD ($)	Dec. 31, 2019USD ($)customermiMW	Jan. 01, 2021USD ($)	Dec. 31, 2020USD ($)county
Business Acquisition [Line Items]
Number of counties In which entity operates | county							8
Goodwill					$ 4,204		$ 4,254
Carrying amount of assets, consolidated variable interest entity				$ 103,702	117,691		127,684
Subsequent Event [Member]
Business Acquisition [Line Items]
Carrying amount of assets, consolidated variable interest entity						$ 6,700
Gulf Power [Member]
Business Acquisition [Line Items]
Cash consideration			$ 4,440
Debt assumed			1,300
Assets assumed			5,200
Property, plant, and equipment			4,000
Regulatory assets			494
Assumed liabilities			3,400
Regulatory liabilities			635
Deferred income taxes			$ 562
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
Florida City Gas [Member]
Business Acquisition [Line Items]
Cash consideration					$ 530
Stanton Energy Center [Member]
Business Acquisition [Line Items]
Membership interests acquired					65.00%
Natural Gas Generation Facilities [Member]
Business Acquisition [Line Items]
Cash consideration					$ 200
FPL [Member] | Subsequent Event [Member]
Business Acquisition [Line Items]
Debt assumed						1,800
Property, plant, and equipment						4,900
Regulatory assets						1,200
Assumed liabilities						3,900
Regulatory liabilities						566
Deferred income taxes						729
Goodwill						$ 2,700
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
NextEra Energy Capital Holdings, Inc. (Consolidated) [Member] | Loans Payable [Member]
Business Acquisition [Line Items]
Proceeds from Short-term Debt				$ 4,500
Trans Bay Cable, LLC [Member]
Business Acquisition [Line Items]
Length of power lines (mi) | mi		53
Florida City Gas [Member] | Florida City Gas [Member]
Business Acquisition [Line Items]
Number of customers served | customer					110,000
Length Of Natural Gas Pipeline | mi					3,700
Oleader Power Project [Member] | Oleader Power Project [Member]
Business Acquisition [Line Items]
Membership interests acquired					100.00%
Natural-Gas Fired, Simple-Cycle Combustion Turbine Electric Generation Facility | MW					791
Entity That Owns Stanton Energy Center Unit A [Member] | Stanton Energy Center [Member]
Business Acquisition [Line Items]
Membership interests acquired					100.00%
Stanton Energy Center [Member] | Stanton Energy Center [Member]
Business Acquisition [Line Items]
Combined-cycle Electric Generation Facility | MW					660
NEET [Member] | GridLiance [Member]
Business Acquisition [Line Items]
Length of power lines (mi) | mi	700
Business Combination, Consideration Transferred	$ 660
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Long-term Debt	$ 160
Number Of FERC-Regulated Transmission Utilities | utlity	3
Number of States in which Entity Operates | state	6
NEET [Member] | GridLiance [Member] | Midwest And Nevada [Member]
Business Acquisition [Line Items]
Number of States in which Entity Operates | state	5

Property, Plant and Equipment_2

Property, Plant and Equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Jointly Owned Utility Plant Interests [Line Items]
Electric plant in service and other property	$ 105,860	$ 96,093
Nuclear fuel	1,604	1,755
Construction work in progress	10,639	9,330
Property, Plant and Equipment, Gross	118,103	107,178
Accumulated Depreciation And Amortization	26,300	25,168
Total property, plant and equipment - net	91,803	82,010	$ 70,334
FPL[Member]
Jointly Owned Utility Plant Interests [Line Items]
Property, Plant and Equipment, Gross	63,230	59,027
Public Utilities, Property, Plant and Equipment Plant in service Gross	57,749	54,523
Nuclear fuel	1,143	1,153
Construction work in progress	$ 4,338	$ 3,351
Percentage of electric generating assets to gross investment in electric utility plant in service (in hundredths)	47.00%	46.00%
Percentage of electric transmission assets to gross investment in electric utility plant in service (in hundredths)	12.00%	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%	7.00%
Amount of reserve (reversal) amortization recognized	$ (1)	$ (357)	$ (541)
FPL's composite depreciation rate for electric plant in service (in hundredths)	3.70%	3.90%	3.80%
AFUDC capitalization rate for FPL (in hundredths)	6.22%	6.22%	5.97%
AFUDC capitalized for FPL	$ 79	$ 80	$ 114
Accumulated depreciation and amortization - FPL	14,297	13,953
Net book value	$ 48,933	45,074
FPL[Member] | Jointly Owned Nuclear Power Plant 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	85.00%
Gross Investment	$ 2,260
Accumulated Depreciation	999
Construction Work in Progress	$ 47
FPL[Member] | Jointly Owned Electricity Generation Plant 1 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	76.00%
Gross Investment	$ 1,300
Accumulated Depreciation	502
Construction Work in Progress	$ 2
Gulf Power [Member] | Jointly Owned Electricity Generation Plant 4 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
Gross Investment	$ 718
Accumulated Depreciation	241
Construction Work in Progress	$ 39
Gulf Power [Member] | Jointly Owned Electricity Generation Plant 5 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	25.00%
Gross Investment	$ 445
Accumulated Depreciation	168
Construction Work in Progress	2
NEER [Member]
Jointly Owned Utility Plant Interests [Line Items]
Interest capitalized on construction projects of NextEra Energy Resources	168	$ 135	$ 94
Net Book Value Of Assets Serving As Collateral	11,000
Total property, plant and equipment - net	$ 1,900
NEER [Member] | Wind plants [Member]
Jointly Owned Utility Plant Interests [Line Items]
Percentage of gross depreciable assets by plant type	55.00%	54.00%
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	13.00%	12.00%
NEER [Member] | Solar plants [Member] | Minimum [Member]
Jointly Owned Utility Plant Interests [Line Items]
Property, plant and equipment, estimated useful lives (in years)	25 years
NEER [Member] | Solar plants [Member] | Maximum [Member]
Jointly Owned Utility Plant Interests [Line Items]
Property, plant and equipment, estimated useful lives (in years)	30 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%	15.00%
NEER [Member] | Nuclear Plant [Member]
Jointly Owned Utility Plant Interests [Line Items]
Percentage of gross depreciable assets by plant type	8.00%	10.00%
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] | Jointly Owned Nuclear Power Plant 3 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	88.23%
Gross Investment	$ 1,290
Accumulated Depreciation	412
Construction Work in Progress	$ 53
NEER [Member] | Jointly Owned Electricity Generation Plant 2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	91.19%
Gross Investment	$ 30
Accumulated Depreciation	9
Construction Work in Progress	$ 1
NEER [Member] | Jointly Owned Electricity Generation Plant 3 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	65.00%
Gross Investment	$ 138
Accumulated Depreciation	13
Construction Work in Progress	$ 0
NEER [Member] | Jointly Owned Electricity Transmission and Distribution System [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	88.23%
Gross Investment	$ 114
Accumulated Depreciation	9
Construction Work in Progress	$ 11

Investments in Partnerships a_3

Investments in Partnerships and Joint Ventures (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Equity method investment, financial statement, reported amounts [Abstract]
Ownership interest in partnerships and joint ventures	$ 5,728	$ 7,453
NextEra Energy Resources' ownership interest, low range (in hundredths)	31.00%
NextEra Energy Resources' ownership interest, high range (in hundredths)	57.00%
Equity method investment, summarized financial information [Abstract]
Net Income (Loss) Attributable to Noncontrolling Interest	$ (550)	(381)	$ (862)
Total assets	127,684	117,691	103,702
Total liabilities	82,755	75,844
Investment in equity method investees	5,728	7,453	6,748
Interest and Fee Income, Other Loans	120	101	$ 94
Due from Related Parties, Current	68	53
Due from Related Parties, Noncurrent	32	33
Guarantor Obligations, Current Carrying Value	288
Equity Method Investment, Nonconsolidated Investee, Other
Equity method investment, summarized financial information [Abstract]
Net Income (Loss) Attributable to Noncontrolling Interest	516	128
Total assets	22,717	20,659
Total liabilities	6,612	6,956
Partners'/members' equity(a)	16,105	13,703
NEER [Member]
Equity method investment, summarized financial information [Abstract]
NEE's share of underlying equity in the principal entities	3,927	3,723
Difference between investment carrying amount and underlying equity in net assets	1,312	3,153
Investment in equity method investees	$ 5,239	6,876
Difference related to goodwill	70.00%
FPL[Member]
Equity method investment, summarized financial information [Abstract]
Total assets	$ 61,610	57,188
Total liabilities	$ 37,870	$ 35,790
Electric Generating Assets To Gross Investment In Electric Utility Plant In Service	47.00%	46.00%
General Facilities Assets To Gross Investment In Electric Utility Plant In Service	6.00%	7.00%
Electric Distribution Assets To Gross Investment In Electric Utility Plant In Service	35.00%	35.00%
NEP OpCo [Member]
Equity method investment, summarized financial information [Abstract]
Difference between investment carrying amount and underlying equity in net assets	$ 2,800	$ 2,800
NEP [Member]
Equity method investment, summarized financial information [Abstract]
Due to Related Parties	10	12
Guarantor Obligations, Current Carrying Value	640
Guarantees, Fair Value Disclosure	31
NEP [Member]
Equity method investment, summarized financial information [Abstract]
Investment in equity method investees		$ 4,400
Mountain Valley Pipeline [Member]
Equity method investment, summarized financial information [Abstract]
Equity Method Investment , Amortization Period Related To Goodwill	$ 1,500
Minimum [Member] | NEER [Member]
Equity method investment, summarized financial information [Abstract]
Amortization period	20 years
Maximum [Member] | NEER [Member]
Equity method investment, summarized financial information [Abstract]
Amortization period	28 years

Variable Interest Entities (V_2

Variable Interest Entities (VIEs) (Details) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2020USD ($)variable_interest_entityentityMW	Dec. 31, 2020USD ($)variable_interest_entityentitymiMW	Dec. 31, 2019USD ($)entityvariable_interest_entityMW	Dec. 31, 2018USD ($)
Variable Interest Entity [Line Items]
Carrying amount of assets, consolidated variable interest entity	$ 127,684	$ 127,684	$ 117,691	$ 103,702
Carrying amount of liabilities, consolidated variable interest entity	82,755	82,755	75,844
Investment in equity method investees	5,728	5,728	7,453	$ 6,748
Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Carrying amount of assets, consolidated variable interest entity	423	423	173
Carrying amount of liabilities, consolidated variable interest entity	68	$ 68	29
Variable Interest Entity, Consolidated, Income Allocation, Percentage		50.00%
Electricity Transmission Line | mi		280
Other variable interest entities [Member]
Variable Interest Entity [Line Items]
Investments in special purpose entities	3,704	$ 3,704	3,247
FPL[Member]
Variable Interest Entity [Line Items]
Carrying amount of assets, consolidated variable interest entity	61,610	61,610	57,188
Carrying amount of liabilities, consolidated variable interest entity	37,870	37,870	35,790
FPL[Member] | Other variable interest entities [Member]
Variable Interest Entity [Line Items]
Investments in special purpose entities	$ 3,124	$ 3,124	$ 2,717
NEER [Member]
Variable Interest Entity [Line Items]
Total Number Of Consolidated Variable Interest Entities | variable_interest_entity	40	40
Wind electric generating facility capability (in megawatts) | MW			220
Investment in equity method investees	$ 5,239	$ 5,239	$ 6,876
NEER [Member] | Variable Interest Entities Gas And Oil Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Carrying amount of assets, consolidated variable interest entity	188	188	216
Carrying amount of liabilities, consolidated variable interest entity	$ 22	$ 22	25
Total Number Of Consolidated Variable Interest Entities | variable_interest_entity	2	2
Natural gas and or oil electric generating facility capacity (in megawatts) | MW		1,450
NEER [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Wind electric generating facility capability (in megawatts) | MW		10,913
Solar generating facility capability | MW		1,377
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	$ 16,200	$ 16,200	11,300
Carrying amount of liabilities, consolidated variable interest entity	$ 1,700	$ 1,700	$ 800
Total Number Of Consolidated Variable Interest Entities	33	33	26
Wind electric generating facility capability (in megawatts) | MW		10,513
Solar generating facility capability | MW		778
NEER [Member] | Variable Interest Entities Gas And Oil Primary Beneficiary 2 [Member] [Domain]
Variable Interest Entity [Line Items]
Number of variable interest entities | entity			3
Indirect Subsidiary of NextEra Energy Resources [Member] | Photovoltaic Solar Facility [Member]
Variable Interest Entity [Line Items]
Carrying amount of assets, consolidated variable interest entity	$ 751	$ 751	$ 776
Carrying amount of liabilities, consolidated variable interest entity	$ 607	$ 607	$ 598
Total Number Of Consolidated Variable Interest Entities | variable_interest_entity	3	3
Ownership percentage (in hundredths)		50.00%
Number of variable interest entities | entity	5	5
Solar generating facility capability | MW		409
Subsidiaries of NEE [Member]
Variable Interest Entity [Line Items]
Equity method investments, additional variable interest entities committed to invest in | variable_interest_entity			5
NextEra Energy Resources Consolidated VIE [Member] | Photovoltaic Solar Facility [Member]
Variable Interest Entity [Line Items]
Carrying amount of assets, consolidated variable interest entity	$ 1,600	$ 1,600
Carrying amount of liabilities, consolidated variable interest entity	$ 400	400
Ownership percentage (in hundredths)	1000.00%
Wind electric generating facility capability (in megawatts) | MW	400
Solar generating facility capability | MW	599
Other Investments [Member] | Subsidiaries of NEE [Member]
Variable Interest Entity [Line Items]
Investment in equity method investees	$ 3,932	$ 3,932	$ 4,254

Leases (Details)

Leases (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)agreement	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)
Lessee, Lease, Description [Line Items]
Number Of Land Use Agreements | agreement	3
ROU assets, operating leases	$ 535	$ 499
Lease liabilities, operating leases	541	498
ROU assets, finance leases	128	62
Lease liabilities, finance leases	$ 124	$ 56
Weighted average incremental borrowing rate at the lease inception, operating leases	3.81%	3.73%
Weighted average incremental borrowing rate at the lease inception, finance leases	3.50%	3.15%
Weighted-average remaining lease term, operating leases	33 years	31 years
Weighted-average remaining lease term, finance leases	25 years	14 years
Expected lease payments over the remaining terms of the leases	$ 1,200
Operating Lease, Expense	95	$ 91
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	121	450
Net investment in sales-type leases	47	$ 50
Losses at commencement of sales-type leases			$ (20)
Expected lease payments over the remaining terms of the power sales agreements	$ 117
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, 2020	Dec. 31, 2019
Asset retirement obligation, roll forward analysis [Roll Forward]
Beginning balance	$ 3,506	$ 3,135
Liabilities incurred	138	100
Accretion expense	169	172
Liabilities settled	(53)	(65)
Revision in estimated cash flows - net	(594)	32
Additions from acquisitions		132
Ending balance	3,166	3,506
Current portion	109	49
Restricted funds included in special use funds [Abstract]
Restricted funds	7,703	6,880
FPL[Member]
Asset retirement obligation, roll forward analysis [Roll Forward]
Beginning balance	2,268	2,147
Liabilities incurred	0	1
Accretion expense	100	107
Liabilities settled	(6)	(1)
Revision in estimated cash flows - net	(558)	14
Additions from acquisitions		0
Ending balance	1,804	2,268
Increase (decrease) in asset retirement obligation		$ (71)
License renewal period		20 years
Current portion	21	$ 0
Restricted funds included in special use funds [Abstract]
Restricted funds	$ 5,271	4,697
FPL[Member] | Jointly Owned Electricity Generation Plant 1 Member
Asset retirement obligation, roll forward analysis [Roll Forward]
Increase (decrease) in asset retirement obligation		$ 75

Employee Retirement Benefits -

Employee Retirement Benefits - Plan Assets, Benefit Obligations and Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Other Postretirement Benefits Plan [Member]
Change in pension benefit obligation:
Service cost	$ 1	$ 1	$ 1
Interest cost	8	9	7
Special termination benefits	0	0	0
Funded status:
Prepaid (accrued) benefit cost	(323)	(313)
Pension Benefits [Member]
Change in pension plan assets:
Plan assets, beginning balance	4,800	3,806
Actual return on plan assets	723	736
Benefit payments	(209)	(235)
Acquisitions	0	493
Plan assets, ending balance	5,314	4,800	3,806
Change in pension benefit obligation:
Obligation, beginning balance	3,363	2,522
Service cost	85	80	70
Interest cost	92	114	82
Acquisitions	0	503
Special termination benefits	16	19	35
Plan amendments	1	3
Actuarial losses - net(c)	259	357
Benefit payments	(209)	(235)
Obligation, ending balance	3,607	3,363	$ 2,522
Funded status:
Prepaid (accrued) benefit cost	1,707	1,437
Accumulated benefit obligation	3,521	3,281
FPL[Member] | Other Postretirement Benefits Plan [Member]
Funded status:
Prepaid (accrued) benefit cost	(155)	(167)
FPL[Member] | Pension Benefits [Member]
Funded status:
Prepaid (accrued) benefit cost	$ 1,554	$ 1,477

Employee Retirement Benefits _2

Employee Retirement Benefits - Unrecognized Amounts (Details) - Pension Benefits [Member] - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Components of AOCI:
Unrecognized prior service benefit	$ 2	$ 2
Unrecognized losses	(60)	(108)
Total	(58)	(106)
Tax effects on components of AOCI [Abstract]
Tax expense (benefit) related to unrecognized prior service benefit (cost)	1	2
Tax expense (benefit) related to unrecognized gain (loss)	(24)	(37)
Unrecognized amounts included in regulatory assets (liabilities) [Abstract]
Unrecognized prior service benefit	(1)	(2)
Unrecognized losses	163	263
Total	$ 162	$ 261

Employee Retirement Benefits _3

Employee Retirement Benefits - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Target asset allocations [Abstract]
Defined contribution expense	$ 64	$ 58	$ 54
Pension Benefits [Member]
Weighted-average assumptions used to determine benefit obligations [Abstract]
Discount rate (in hundredths)	2.53%	3.22%
Salary increase (in hundredths)	4.40%	4.40%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Weighted-Average Interest Crediting Rate	3.82%	3.83%
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	$ 37	$ 36	$ 34

Employee Retirement Benefits _4

Employee Retirement Benefits - Fair Value of Pension Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Fair Value Measured at Net Asset Value Per Share
Fair value measurements of plan assets [Abstract]
Foreign investments	$ 153	$ 190
Equity Securities [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	881	741
Equity Securities [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	2,030	1,605
Equity Securities [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	2,017	1,593
Equity Securities [Member] | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	10	9
Equity Securities [Member] | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	3	3
Equity Commingled Vehicles [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	156	141
Equity Commingled Vehicles [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	668	706
Equity Commingled Vehicles [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Equity Commingled Vehicles [Member] | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	668	706
Equity Commingled Vehicles [Member] | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
U.S. Government And Municipal Bonds [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	177	102
U.S. Government And Municipal Bonds [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	169	95
U.S. Government And Municipal Bonds [Member] | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	8	7
U.S. Government And Municipal Bonds [Member] | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Corporate debt securities [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	93	76
Corporate debt securities [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	340	247
Corporate debt securities [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Corporate debt securities [Member] | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	340	247
Corporate debt securities [Member] | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Asset-backed securities [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	375	416
Asset-backed securities [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Asset-backed securities [Member] | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	375	416
Asset-backed securities [Member] | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
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] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	201	190
Debt Security Commingled Vehicles [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	47
Debt Security Commingled Vehicles [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair value measurements of plan assets [Abstract]
Fair value	201	143
Debt Security Commingled Vehicles [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Convertible securities [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	35	5
Convertible securities [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	517	404
Convertible securities [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	64	32
Convertible securities [Member] | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	453	372
Convertible securities [Member] | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
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		20
Total Investments
Fair value measurements of plan assets [Abstract]
Fair value	5,314	4,800
Total Investments | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	4,308	3,670
Total Investments | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	2,250	1,767
Total Investments | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	2,055	1,900
Total Investments | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	3	3
Total Investments | Fair Value Measured at Net Asset Value Per Share | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	$ 1,006	$ 1,130

Employee Retirement Benefits _5

Employee Retirement Benefits - Expected Cash Flows (Details) - Pension Benefits [Member] $ in Millions	Dec. 31, 2020USD ($)
Defined Benefit Plan Disclosure [Line Items]
2020	$ 228
2021	200
2022	202
2023	204
2024	206
2026 - 2030	$ 1,024

Employee Retirement Benefits _6

Employee Retirement Benefits - Net Periodic Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Pension Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Service cost	$ 85	$ 80	$ 70
Interest cost	92	114	82
Expected return on plan assets	(321)	(312)	(276)
Amortization of actuarial loss	18	0	0
Amortization of prior service benefit	(1)	(1)	(1)
Special termination benefits	16	19	35
Net periodic (income) cost	(111)	(100)	(90)
Other Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Service cost	1	1	1
Interest cost	8	9	7
Expected return on plan assets	0	0	0
Amortization of actuarial loss	3	0	0
Amortization of prior service benefit	(16)	(15)	(15)
Special termination benefits	0	0	0
Net periodic (income) cost	(4)	(5)	(7)
FPL[Member] | Pension Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Net periodic (income) cost	(77)	(71)	(57)
FPL[Member] | Other Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Net periodic (income) cost	$ (3)	$ (4)	$ (6)

Employee Retirement Benefits _7

Employee Retirement Benefits - Net Periodic Income Cost Recognizedf for OCI (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Reclassification from accumulated other comprehensive income (loss) to net income	$ 2	$ (3)	$ (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)	42	(36)	(13)
Reclassification from accumulated other comprehensive income (loss) to net income	5	0	0
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax and Reclassification Adjustment, Attributable to Parent	47	(36)	(13)
Tax effects on components of net periodic income (cost) recognized in OCI [Abstract]
Net gains (losses)	13	$ (10)	$ 4
Reclassification from accumulated other comprehensive income (loss) to net income, tax expense (benefit)	$ 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, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost Recognized In Regulatory Assets Liabilities	$ 1	$ 0
Unrecognized gains	(89)	(113)
Amortization of prior service cost	1	1
Amortization Of Unrecognized Losses Recognized In Regulatory Assets Liabilities	(12)	0
Total	$ (99)	$ (112)

Employee Retirement Benefits _9

Employee Retirement Benefits - Assumptions Used for Periodic Income (Details) - Pension Benefits [Member]	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Discount rate	3.22%	4.26%	3.59%
Salary increase	4.40%	4.40%	4.10%
Expected long-term rate of return, net of management fees	7.35%	7.35%	7.35%

Debt (Schedule of Debt Instrume

Debt (Schedule of Debt Instruments) (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Less current maturities of long-term debt	$ 4,138	$ 2,124
Long-term debt, excluding current maturities	41,944	37,543
Repayment prior to maturity	4,138
FPL[Member]
Debt Instrument [Line Items]
Unamortized debt issuance costs and discount	(168)	(156)
Total long-term debt	15,676	14,161
Less current maturities of long-term debt	54	30
Long-term debt, excluding current maturities	15,622	14,131
Repayment prior to maturity	54
FPL[Member] | First mortgage bonds - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 13,090	$ 12,005
Weighted-average interest rate	4.32%	4.46%
FPL[Member] | Pollution control, solid waste disposal and industrial development revenue bonds - primary variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 948	$ 1,076
Weighted-average interest rate	0.12%	1.67%
Variable rate tax exempt bonds	$ 948
FPL[Member] | Senior Unsecured Notes - Variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 1,806	$ 1,236
Weighted-average interest rate	0.44%	2.18%
Floating rate notes that permit individual noteholders to require repayment prior to maturity	$ 556
Gulf Power [Member]
Debt Instrument [Line Items]
Unamortized debt issuance costs and discount	(14)	$ (14)
Total long-term debt	1,560	1,685
Less current maturities of long-term debt	300	175
Long-term debt, excluding current maturities	1,260	1,510
Gulf Power [Member] | Other Long-Term Debt - Primarily Variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 759	$ 709
Weighted-average interest rate	0.70%	1.93%
Variable rate tax exempt bonds	$ 426
Gulf Power [Member] | Senior unsecured notes -fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 815	$ 990
Weighted-average interest rate	4.05%	4.17%
NEER [Member]
Debt Instrument [Line Items]
Unamortized debt issuance costs and premium	$ (65)	$ (74)
Total long-term debt	4,647	4,622
Less current maturities of long-term debt	239	215
Long-term debt, excluding current maturities	4,408	4,407
NEER [Member] | Other Long-Term Debt - Primarily Variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 450	$ 440
Weighted-average interest rate	2.72%	3.78%
NEER [Member] | Other long-term debt - fixed [Member] | NEET [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 937	$ 837
Weighted-average interest rate	3.09%	3.50%
NEER [Member] | Senior secured limited-recourse term loans - primarily variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 3,325	$ 3,419
Weighted-average interest rate	2.33%	3.79%
Capital Holdings [Member]
Debt Instrument [Line Items]
Unamortized debt issuance costs, premium and discount	$ (115)	$ (139)
Total long-term debt	24,199	19,199
Less current maturities of long-term debt	3,545	1,704
Long-term debt, excluding current maturities	20,654	17,495
Capital Holdings [Member] | Other long-term debt - variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 600	$ 750
Weighted-average interest rate	0.70%	2.60%
Capital Holdings [Member] | Other long-term debt - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 221	$ 524
Weighted-average interest rate	0.92%	2.00%
Capital Holdings [Member] | Debentures - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 11,540	$ 9,550
Weighted-average interest rate	2.86%	3.05%
Capital Holdings [Member] | Debentures variable [Domain]
Debt Instrument [Line Items]
Long-term debt, gross	$ 1,225	$ 1,375
Weighted-average interest rate	0.80%	3.00%
Capital Holdings [Member] | Debentures, related to NEE's equity units - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 6,000	$ 1,500
Weighted-average interest rate	1.46%	2.10%
Capital Holdings [Member] | Junior subordinated debentures - primarily fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 3,693	$ 4,643
Weighted-average interest rate	4.78%	5.13%
Capital Holdings [Member] | Japanese yen denominated term loans - variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 650	$ 645
Weighted-average interest rate	1.49%	3.10%
Capital Holdings [Member] | Australian dollar denominated long-term debt - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 385	$ 351
Weighted-average interest rate	2.20%	2.59%
Other Current Liabilities [Member]
Debt Instrument [Line Items]
Current other liabilities		$ 133
Other Current Liabilities [Member] | NEER [Member] | Other Long Term Debt [Member]
Debt Instrument [Line Items]
Current other liabilities	$ 463

Debt (Minimum Annual Maturities

Debt (Minimum Annual Maturities) (Details) $ in Millions	Dec. 31, 2020USD ($)
Debt Instrument [Line Items]
Year One	$ 4,138
Year Two	2,471
Year Three	3,329
Year Four	3,564
Year Five	7,640
FPL[Member]
Debt Instrument [Line Items]
Year One	54
Year Two	96
Year Three	1,765
Year Four	646
Year Five	$ 1,700

Debt (Narrative) (Details)

Debt (Narrative) (Details) - USD ($)	1 Months Ended			3 Months Ended		12 Months Ended
	Sep. 30, 2020	Feb. 29, 2020	Sep. 30, 2019	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2020	Dec. 31, 2019	Aug. 31, 2019	Aug. 31, 2018
Debt Instrument [Line Items]
Weighted-average interest rate of commercial paper and short-tem borrowings (in hundredths)						0.35%	1.95%
Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity						$ 11,900,000,000
Letter of Credit [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity						65,000,000
Revolving Credit Facility [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity						11,800,000,000
Revolving Credit Facility, Issuance of Letters of Credit [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity						$ 2,000,000,000
FPL[Member]
Debt Instrument [Line Items]
Weighted-average interest rate of commercial paper and short-tem borrowings (in hundredths)						0.17%	1.80%
FPL[Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity						$ 3,600,000,000
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						3,600,000,000
FPL[Member] | Revolving Credit Facility, Issuance of Letters of Credit [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Available capacity						$ 572,000,000
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)						0.7092
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)						0.5672
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)						$ 70.51
NEE Equity Units February 2020 [Member] | Maximum [Member]
Sale of equity units [Abstract]
Adjusted Threshold Appreciation Price						$ 88.14
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)						0.6764
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)						0.5412
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)						$ 73.93
NEE Equity Units September 2020 [Member] | Maximum [Member]
Sale of equity units [Abstract]
Adjusted Threshold Appreciation Price						$ 92.41
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)						0.8940
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)						0.7156
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)						$ 55.93
NEE Equity Units September 2019 [Member] | Maximum [Member]
Sale of equity units [Abstract]
Adjusted Threshold Appreciation Price						$ 69.91
Series H Debentures Due September 1, 2020 [Member] | NextEra Energy Capital Holdings, Inc. [Member] | Debentures [Member]
Sale of equity units [Abstract]
Interest rate									3.342%
Debt Instrument, Face Amount									$ 700,000,000
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
September 2015 Equity Units Stock Split [Member]
Sale of equity units [Abstract]
Sale of Stock, Number of Shares Issued in Transaction					6,200,000	24,900,000
Sale of Stock, Consideration Received on Transaction					$ 700,000,000
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) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Reconciliation of basic and diluted earnings per share of common stock [Abstract]
Net income (loss) attributable to NEE									$ 2,919	$ 3,769	$ 6,638
Dilutive Securities, Effect on Basic Earnings Per Share									0	0	(19)
Net Income (Loss) Attributable to Parent, Diluted									$ 2,919	$ 3,769	$ 6,619
Denominator:
Weighted-average number of common shares outstanding - basic									1,959	1,927.9	1,892.8
Equity units, stock options, performance share awards, forward sale agreements and restricted stock									9.8	14	15.1
Weighted-average number of common shares outstanding - assuming dilution									1,968.8	1,941.9	1,907.9
Earnings per share attributable to NEE:
Basic	$ 0	$ 0.63	$ 0.65	$ 0.21	$ 0.50	$ 0.46	$ 0.64	$ 0.36	$ 1.49	$ 1.95	$ 3.51
Assuming dilution	$ 0	$ 0.62	$ 0.65	$ 0.21	$ 0.50	$ 0.45	$ 0.64	$ 0.35	$ 1.48	$ 1.94	$ 3.47
Antidilutive securities (in shares)									27.1	3	0.5

Equity (Issuance of Stock and F

Equity (Issuance of Stock and Forward Sale Agreement) (Details) $ in Millions	Oct. 26, 2020shares	Sep. 14, 2020shares	Nov. 30, 2017USD ($)	Dec. 31, 2020USD ($)shares	Dec. 31, 2019shares	Dec. 31, 2018shares	Dec. 31, 2017USD ($)
Class of Stock [Line Items]
Antidilutive securities (in shares) | shares				27,100,000	3,000,000	500,000
Common stock, authorized (in shares) | shares	3,200,000,000	800,000,000		3,200,000,000	3,200,000,000
Stockholders' Equity Note, Stock Split, Conversion Ratio	4	4
NEP [Member]
Class of Stock [Line Items]
Senior unsecured convertible notes outstanding | $				$ 600			$ 300
Series A Convertible Preferred Units [Member] | NEP [Member]
Class of Stock [Line Items]
Stock sold during the period | $			$ 550

Equity (Stock-Based Compensatio

Equity (Stock-Based Compensation) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Stock-based compensation
Stock based compensation costs	$ 107	$ 100	$ 82
Tax benefits related to stock-based compensation arrangements	21	$ 17	$ 21
Unrecognized stock based compensation costs	$ 109
Unrecognized stock based compensation costs weighted-average period of recognition (in years)	1 year 8 months 12 days
Common stock authorized for awards (in shares)	60,000,000
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, 2020	Dec. 31, 2019	Dec. 31, 2018
Restricted Stock Awards [Member]
Activity [Roll Forward]
Nonvested balance at beginning of year (in shares)	1,980,592
Granted (in shares)	631,186
Vested (in shares)	(870,780)
Forfeited (in shares)	(66,756)
Nonvested balance at end of year (in shares)	1,674,242	1,980,592
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)	$ 39.93
Granted, weighted-average grant date fair value (in dollars per share)	68.25	$ 46.64	$ 38.92
Vested, weighted-average grant date fair value (in dollars per share)	39.58
Forfeited, weighted-average grant date fair value (in dollars per share)	49.21
Nonvested balance at end of year, weighted-average grant date fair value (in dollars per share)	$ 50.26	$ 39.93
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)	2,680,584
Granted (in shares)	1,535,436
Vested (in shares)	(2,081,264)
Forfeited (in shares)	(196,148)
Nonvested balance at end of year (in shares)	1,938,608	2,680,584
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)	$ 35.61
Granted, weighted-average grant date fair value (in dollars per share)	46.09	$ 34.75	$ 31.06
Vested, weighted-average grant date fair value (in dollars per share)	32.93
Forfeited, weighted-average grant date fair value (in dollars per share)	44.85
Nonvested balance at end of year, weighted-average grant date fair value (in dollars per share)	$ 47.46	$ 35.61
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	$ 177	$ 125	$ 115
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, 2020	Dec. 31, 2019	Dec. 31, 2018
Assumptions used to estimate the fair value of options using the Black-Scholes option pricing model [Abstract]
Expected volatility (in hundredths)			14.41%
Expected dividends (in hundredths)			3.05%
Expected term (years)	7 years	7 years	7 years
Risk-free rate (in hundredths)			2.83%
Option activity [Roll Forward]
Shares underlying options - Balance at beginning of year (in shares)	9,666,752
Shares underlying options - Granted (in shares)	1,519,712
Shares underlying options - Exercised (in shares)	(1,513,324)
Shares underlying options - forfeited (in shares)	54,936
Shares underlying options - Balance at end of year (in shares)	9,618,204	9,666,752
Shares underlying options - Exercisable (in shares)	6,382,356
Additional disclosures pertaining to options [Abstract]
Balance at beginning of year, weighted average exercise price (in dollars per share)	$ 30.77
Granted, weighted average exercise price (in dollars per share)	68.76
Exercised, weighted average exercise price (in dollars per share)	64.53
Forfeited, weighted average exercise price (in dollars per share)	59.18
Balance at end of year, weighted average exercise price (in dollars per share)	38.32	$ 30.77
Exercisable at end of year, weighted average exercise price (in dollars per share)	$ 29.69
Balance at end of year, weighted average remaining contractual term (years)	6 years 2 months 12 days
Exercisable at end of year, weighted average remaining contractual term (years)	5 years 1 month 6 days
Balance at end of year, aggregate intrinsic value	$ 373
Exercisable at end of year, aggregate intrinsic value	$ 303
Granted, weighted average grant date fair value (in dollars per share)	$ 7.08	$ 5.01	$ 4.51
Total intrinsic value of stock options exercised	$ 71,000,000	$ 81,000,000	$ 35,000,000
Cash received from option exercises	30,000,000	34,000,000	18,000,000
Tax benefit realized from options exercised	$ 17,000,000	$ 19,000,000	$ 9,000,000
Minimum [Member]
Assumptions used to estimate the fair value of options using the Black-Scholes option pricing model [Abstract]
Expected volatility (in hundredths)	14.63%	14.20%
Expected dividends (in hundredths)	2.50%	2.85%
Risk-free rate (in hundredths)	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)	16.31%	14.31%
Expected dividends (in hundredths)	2.72%	2.93%
Risk-free rate (in hundredths)	1.52%	2.54%

Equity (Additional Disclosures

Equity (Additional Disclosures Regarding Common and Preferred Stock) (Details)	Dec. 31, 2020$ / 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
Outstanding (in shares)	0
Preferred Stock, $100 Par Value [Member] | FPL [Member]
Preferred stock [Abstract]
Authorized (in shares)	10,414,100
Par value (in dollars per share) | $ / shares	$ 100
Preferred Stock, No Par Value [Member] | FPL [Member]
Preferred stock [Abstract]
Authorized (in shares)	5,000,000
Par value (in dollars per share) | $ / shares	$ 0
Outstanding (in shares)	0
Preferred Stock, No Par Value [Member] | FPL [Member] | Subordinated Preferred Stock [Member]
Preferred stock [Abstract]
Authorized (in shares)	5,000,000
Par value (in dollars per share) | $ / shares	$ 0
Outstanding (in shares)	0

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	$ (169)	$ (188)	$ 111
Other comprehensive income (loss) before reclassifications	63	(3)	(53)
Amounts reclassified from AOCI	11	24	24
Total other comprehensive income (loss), net of tax	74	21	(29)
AOCI Impact of NEP Deconsolidation			58
Less other comprehensive income attributable to noncontrolling interests	7	1
Acquisition of Gulf Power		(1)
AOCI Impact of Disposal of a Business	10
Accumulated other comprehensive loss, ending	(92)	(169)	(188)
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	(8)
Accumulated Other Comprehensive Income (Loss), Noncontrolling Interest And Parent, Net of Tax	(84)
Cumulative Effect, Period of Adoption, Adjustment [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning			(328)
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	(27)	(55)	(77)
Other comprehensive income (loss) before reclassifications	0	0	0
Amounts reclassified from AOCI	12	29	26
Total other comprehensive income (loss), net of tax	12	29	26
AOCI Impact of NEP Deconsolidation			3
Less other comprehensive income attributable to noncontrolling interests	0	0
Acquisition of Gulf Power		(1)
AOCI Impact of Disposal of a Business	23
Accumulated other comprehensive loss, ending	8	(27)	(55)
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	0
Accumulated Other Comprehensive Income (Loss), Noncontrolling Interest And Parent, Net of Tax	8
Net Unrealized Gains (Losses) on Cash Flow Hedges | Cumulative Effect, Period of Adoption, Adjustment [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning			(7)
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	11	(7)	316
Other comprehensive income (loss) before reclassifications	12	20	(12)
Amounts reclassified from AOCI	(3)	(2)	1
Total other comprehensive income (loss), net of tax	9	18	(11)
AOCI Impact of NEP Deconsolidation			0
Less other comprehensive income attributable to noncontrolling interests	0	0
Acquisition of Gulf Power		0
AOCI Impact of Disposal of a Business	0
Accumulated other comprehensive loss, ending	20	11	(7)
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	0
Accumulated Other Comprehensive Income (Loss), Noncontrolling Interest And Parent, Net of Tax	20
Net Unrealized Gains (Losses) on Available for Sale Securities | Cumulative Effect, Period of Adoption, Adjustment [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning			(312)
Defined Benefit Pension and Other Benefits Plans
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	(114)	(65)	(39)
Other comprehensive income (loss) before reclassifications	37	(46)	(14)
Amounts reclassified from AOCI	2	(3)	(3)
Total other comprehensive income (loss), net of tax	39	(49)	(17)
AOCI Impact of NEP Deconsolidation			0
Less other comprehensive income attributable to noncontrolling interests	0	0
Acquisition of Gulf Power		0
AOCI Impact of Disposal of a Business	0
Accumulated other comprehensive loss, ending	(75)	(114)	(65)
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	0
Accumulated Other Comprehensive Income (Loss), Noncontrolling Interest And Parent, Net of Tax	(75)
Defined Benefit Pension and Other Benefits Plans | Cumulative Effect, Period of Adoption, Adjustment [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning			(9)
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	(42)	(63)	(69)
Other comprehensive income (loss) before reclassifications	13	22	(31)
Amounts reclassified from AOCI	0	0	0
Total other comprehensive income (loss), net of tax	13	22	(31)
AOCI Impact of NEP Deconsolidation			37
Less other comprehensive income attributable to noncontrolling interests	7	1
Acquisition of Gulf Power		0
AOCI Impact of Disposal of a Business	(13)
Accumulated other comprehensive loss, ending	(49)	(42)	(63)
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	(8)
Accumulated Other Comprehensive Income (Loss), Noncontrolling Interest And Parent, Net of Tax	(41)
Net Unrealized Gains (Losses) on Foreign Currency Translation | Cumulative Effect, Period of Adoption, Adjustment [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning			0
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	3	2	(20)
Other comprehensive income (loss) before reclassifications	1	1	4
Amounts reclassified from AOCI	0	0	0
Total other comprehensive income (loss), net of tax	1	1	4
AOCI Impact of NEP Deconsolidation			18
Less other comprehensive income attributable to noncontrolling interests	0	0
Acquisition of Gulf Power		0
AOCI Impact of Disposal of a Business	0
Accumulated other comprehensive loss, ending	4	$ 3	2
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	0
Accumulated Other Comprehensive Income (Loss), Noncontrolling Interest And Parent, Net of Tax	$ 4
Other Comprehensive Income (Loss) Related to Equity Method Investees | Cumulative Effect, Period of Adoption, Adjustment [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning			$ 0

Commitments and Contingencies_2

Commitments and Contingencies (Estimated Planned Capital Expenditures) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)MW
Planned Capital Expenditures [Line Items]
Guarantor Obligations, Current Carrying Value	$ 288
FPL[Member]
Planned Capital Expenditures [Line Items]
2021	6,890
2022	6,630
2023	6,480
2024	6,710
2025	6,695
Total	33,405
FPL[Member] | New Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
2021	780
2022	880
2023	680
2024	540
2025	530
Total	3,410
FPL[Member] | Existing Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
2021	1,085
2022	1,155
2023	1,045
2024	1,010
2025	750
Total	5,045
FPL[Member] | Transmission and Distribution Expenditures [Member]
Planned Capital Expenditures [Line Items]
2021	4,065
2022	3,665
2023	3,825
2024	4,290
2025	4,490
Total	20,335
Planned Generation Capital Expenditures AFUDC First Year	50
Planned Generation Capital Expenditures AFUDC Second Year	50
Planned Generation Capital Expenditures AFUDC Third Year	40
Planned Generation Capital Expenditures AFUDC Fourth Year	55
Planned Generation Capital Expenditures AFUDC Fifth Year	45
FPL[Member] | Nuclear Fuel Expenditures [Member]
Planned Capital Expenditures [Line Items]
2021	220
2022	170
2023	120
2024	145
2025	145
Total	800
FPL[Member] | General and Other Expenditures [Member]
Planned Capital Expenditures [Line Items]
2021	740
2022	760
2023	810
2024	725
2025	780
Total	3,815
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	50
Planned Generation Capital Expenditures AFUDC Third Year	25
Planned Generation Capital Expenditures AFUDC Fourth Year	15
Planned Generation Capital Expenditures AFUDC Fifth Year	15
Gulf Power [Member]
Planned Capital Expenditures [Line Items]
2021	860
2022	695
2023	625
2024	685
2025	685
Total	3,550
NEER [Member]
Planned Capital Expenditures [Line Items]
2021	5,140
2022	905
2023	455
2024	295
2025	295
Total	7,090
NEER [Member] | Wind Expenditures [Member]
Planned Capital Expenditures [Line Items]
2021	1,770
2022	60
2023	15
2024	15
2025	5
Total	$ 1,865
Planned New Generation To Be Added over 5 Years | MW	2,394
NEER [Member] | Solar Expenditures [Member]
Planned Capital Expenditures [Line Items]
2021	$ 1,565
2022	340
2023	185
2024	0
2025	0
Total	$ 2,090
Planned New Generation To Be Added over 5 Years | MW	2,354
NEER [Member] | Battery Storage Expenditures [Member]
Planned Capital Expenditures [Line Items]
2021	$ 355
2022	0
2023	0
2024	0
2025	0
Total	355
NEER [Member] | Nuclear Expenditures [Member]
Planned Capital Expenditures [Line Items]
2021	230
2022	190
2023	145
2024	190
2025	200
Total	955
NEER [Member] | Pipelines [Member]
Planned Capital Expenditures [Line Items]
2021	285
2022	165
2023	0
2024	0
2025	0
Total	450
NEER [Member] | Rate-Regulated Transmission [Member]
Planned Capital Expenditures [Line Items]
2021	205
2022	25
2023	10
2024	15
2025	30
Total	285
NEER [Member] | Other Expenditures [Member]
Planned Capital Expenditures [Line Items]
2021	730
2022	125
2023	100
2024	75
2025	60
Total	$ 1,090

Commitments and Contingencies_3

Commitments and Contingencies (Required Capacity and/or Minimum Payments Under Contracts) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
FPL[Member]
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2021	$ 1,030
Capacity payments and/or minimum payments - 2022	970
Capacity payments and/or minimum payments - 2023	950
Capacity payments and/or minimum payments - 2024	940
Capacity payments and/or minimum payments - 2025	890
Capacity payments and/or minimum payments - Thereafter	9,380
Related Party Transaction, Amounts of Transaction	386	$ 316	$ 303
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 - 2021	415
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 - Thereafter	6,360
NEER [Member]
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2021	3,250
Capacity payments and/or minimum payments - 2022	530
Capacity payments and/or minimum payments - 2023	210
Capacity payments and/or minimum payments - 2024	210
Capacity payments and/or minimum payments - 2025	140
Capacity payments and/or minimum payments - Thereafter	1,635
Commitment to invest	85
Joint Obligations First Year	480
Joint Obligations Second Year	20
Joint Obligations Third Year	20
Joint Obligations Fourth Year	10
Joint Obligations Fifth Year	10
Joint Obligations After Fifth Year	5
NEER [Member] | Mountain Valley Pipeline [Member]
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2022	25
Capacity payments and/or minimum payments - 2023	70
Capacity payments and/or minimum payments - 2024	70
Capacity payments and/or minimum payments - 2025	70
Capacity payments and/or minimum payments - Thereafter	1,155
NEER [Member] | Contract Group 1 [Member]
Long-term Purchase Commitment [Line Items]
Commitment amount included in capital expenditures	$ 3,400
Join Venture [Member] | NEER [Member]
Long-term Purchase Commitment [Line Items]
Ownership interest	31.50%
Consolidation, Eliminations [Member] | FPL[Member]
Long-term Purchase Commitment [Line Items]
Related Party Transaction, Amounts of Transaction	$ 108	$ 108	$ 95

Commitments and Contingencies_4

Commitments and Contingencies (Insurance) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)
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	13,300
Potential retrospective assessments under secondary financial protection system	1,100
Potential retrospective assessments under secondary financial protection system payable per incident per year	164
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	173
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 nuclear liability secondary financial protection	41
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	4
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	106
Duane Arnold Energy Center Insurance [Member]
Insurance [Abstract]
Amount of sublimit for non nuclear perils per occurrence per site under nuclear insurance mutual companies for property damage decontamination and premature decommissioning risks	$ 500

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue		$ 17,997	$ 19,204	$ 16,727
Operating expenses - net		13,234	14,257	12,527
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal		353	406	80
Interest expense		1,950	2,249	1,498
Interest income		38	54	51
Depreciation and amortization		4,052	4,216	3,911
Equity in earnings (losses) of equity method investees		(1,351)	66	358
Income Tax Expense (Benefit)		44	448	1,576
Net income (loss)		2,369	3,388	5,776
Net income (loss) attributable to NEE		2,919	3,769	6,638
Capital expenditures, independent power and other investments and nuclear fuel purchases		14,610	17,462	13,004
Total property, plant and equipment - net		91,803	82,010	70,334
Total assets		127,684	117,691	103,702
Investment in equity method investees		5,728	7,453	6,748
FPL[Member]
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue		11,662	12,192	11,862
Operating expenses - net		7,862	8,890	8,708
Interest expense		600	594	541
Depreciation and amortization		2,246	2,524	2,633
Income Tax Expense (Benefit)		610	441	539
Net income (loss)	[1]	2,650	2,334	2,171
Electric utility plant and other property - net		48,933	45,074
Total assets		$ 61,610	57,188
NEER [Member]
Segment Reporting Information [Line Items]
Deemed capital structure of NextEra Energy Resources (in hundredths)		70.00%
Operating Segments [Member] | FPL[Member]
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue		$ 11,662	12,192	11,862
Operating expenses - net		7,862	8,895	8,714
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal		0	5	6
Interest expense		600	594	541
Interest income		2	5	4
Depreciation and amortization		2,246	2,524	2,633
Equity in earnings (losses) of equity method investees		0	0	0
Income Tax Expense (Benefit)		610	441	539
Net income (loss)		2,650	2,334	2,171
Net income (loss) attributable to NEE		2,650	2,334	2,171
Capital expenditures, independent power and other investments and nuclear fuel purchases		6,680	5,755	5,135
Electric utility plant and other property - net		48,933	45,074	41,499
Total assets		61,610	57,188	53,484
Investment in equity method investees		0	0	0
Operating Segments [Member] | Gulf Power Segment [Member]
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue		1,398	1,487
Operating expenses - net		1,081	1,216
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal		0	0
Interest expense		41	55
Interest income		2	3
Depreciation and amortization		281	247
Equity in earnings (losses) of equity method investees		0	0
Income Tax Expense (Benefit)		67	42
Net income (loss)		238	180
Net income (loss) attributable to NEE		238	180
Capital expenditures, independent power and other investments and nuclear fuel purchases		1,012	729
Electric utility plant and other property - net		4,946	4,763
Total assets		6,725	5,855
Investment in equity method investees		0	0
Operating Segments [Member] | NEER [Member]
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue		5,046	5,639	4,984
Operating expenses - net		4,125	4,037	3,698
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal		363	402	82
Interest expense		659	873	595
Interest income		28	38	40
Depreciation and amortization		1,460	1,387	1,230
Equity in earnings (losses) of equity method investees		(1,351)	67	321
Income Tax Expense (Benefit)		(416)	162	1,196
Net income (loss)		(19)	1,426	3,842
Net income (loss) attributable to NEE		531	1,807	4,704
Capital expenditures, independent power and other investments and nuclear fuel purchases		6,893	6,505	7,189
Total property, plant and equipment - net		37,842	32,042	28,602
Total assets		55,633	51,516	44,509
Investment in equity method investees		5,713	7,453	6,521
Corporate, Non-Segment [Member] | Corporate and Other [Member] | Corporate and Other [Member]
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue		(109)	(114)	(119)
Operating expenses - net		166	109	115
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal		(10)	(1)	(8)
Interest expense		650	727	362
Interest income		6	8	7
Depreciation and amortization		65	58	48
Equity in earnings (losses) of equity method investees		0	(1)	37
Income Tax Expense (Benefit)		(217)	(197)	(159)
Net income (loss)		(500)	(552)	(237)
Net income (loss) attributable to NEE		(500)	(552)	(237)
Capital expenditures, independent power and other investments and nuclear fuel purchases		25	4,473	680
Total property, plant and equipment - net		82	131	233
Total assets		3,716	3,132	5,709
Investment in equity method investees		$ 15	$ 0	$ 227
[1]	FPL's comprehensive income is the same as reported net income.

Quarterly Data (Unaudited) (Det

Quarterly Data (Unaudited) (Details) - $ / shares	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Condensed consolidated quarterly financial information [Abstract]
Basic EPS - Net income (in dollars per share)	$ 0	$ 0.63	$ 0.65	$ 0.21	$ 0.50	$ 0.46	$ 0.64	$ 0.36	$ 1.49	$ 1.95	$ 3.51
Diluted EPS - Net income (in dollars per share)	0	0.62	0.65	0.21	0.50	0.45	0.64	0.35	1.48	1.94	3.47
Dividends per share of common stock (in dollars per share)	0.35	0.35	0.35	0.35	0.3125	0.3125	0.3125	0.3125	$ 1.40	$ 1.25	$ 1.11
High common stock sales price (in dollars per share)	83.34	74.82	65.56	70.84	61.25	58.36	52.23	48.89
Low common stock sales price (in dollars per share)	$ 69.63	$ 59.58	$ 53.26	$ 43.70	$ 55.17	$ 50.27	$ 46.82	$ 42.17