NextEra Energy (NEE) 10-K 17 Feb 23 2022 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2022	Jan. 31, 2023	Jun. 30, 2022
Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2022
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			$ 152,043,646,294
Entity Common Stock, Shares Outstanding		1,987,495,306
Entity Central Index Key	0000753308
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	FY
Amendment Flag	false
ICFR Auditor Attestation Flag	true
Documents Incorporated by Reference	Portions of NextEra Energy, Inc.'s Proxy Statement for the 2023 Annual Meeting of Shareholders are incorporated by reference in Part III hereof. __________________________________ This combined Form 10-K represents separate filings by NextEra Energy, Inc. and Florida Power & Light Company. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Florida Power & Light Company makes no representations as to the information relating to NextEra Energy, Inc.'s other operations. Florida Power & Light Company meets the conditions set forth in General Instruction I.(1)(a) and (b) of Form 10-K and is therefore filing this Form with the reduced disclosure format.
Common Stock [Member]
Entity Information [Line Items]
Title of 12(b) Security	Common Stock, $0.01 Par Value
Trading Symbol	NEE
Security Exchange Name	NYSE
Corporate Units 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
Corporate Units 6.926%
Entity Information [Line Items]
Title of 12(b) Security	6.926% Corporate Units
Trading Symbol	NEE.PRR
Security Exchange Name	NYSE
FPL [Member]
Entity Information [Line Items]
Entity File Number	2-27612
Entity Registrant Name	FLORIDA POWER & LIGHT CO
Entity Tax Identification Number	59-0247775
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		1,000
Entity Central Index Key	0000037634
Current Fiscal Year End Date	--12-31

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2022
Auditor Information [Abstract]
Auditor Name	Deloitte & Touche LLP
Auditor Location	Boca Raton, Florida
Auditor Firm ID	34

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
OPERATING REVENUES	$ 20,956	$ 17,069	$ 17,997
OPERATING EXPENSES
Fuel, purchased power and interchange	6,389	4,527	3,539
Other operations and maintenance	4,428	3,981	3,934
Depreciation and amortization	4,503	3,924	4,052
Taxes other than income taxes and other – net	2,077	1,801	1,709
Total operating expenses – net	17,397	14,233	13,234
GAINS ON DISPOSAL OF BUSINESSES/ASSETS – NET	522	77	353
OPERATING INCOME	4,081	2,913	5,116
OTHER INCOME (DEDUCTIONS)
Interest Expense	(585)	(1,270)	(1,950)
Equity in earnings (losses) of equity method investees	203	666	(1,351)
Allowance for equity funds used during construction	112	142	93
Gains on disposal of investments and other property – net	80	70	50
Change in unrealized gains (losses) on equity securities held in NEER's nuclear decommissioning funds – net	(461)	267	163
Other net periodic benefit income	202	257	200
Other – net	200	130	92
Total other income (deductions) – net	(249)	262	(2,703)
INCOME BEFORE INCOME TAXES	3,832	3,175	2,413
INCOME TAXES	586	348	44
NET INCOME	3,246	2,827	2,369
NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	901	746	550
NET INCOME ATTRIBUTABLE TO NEE	$ 4,147	$ 3,573	$ 2,919
Earnings per share attributable to NEE:
Basic	$ 2.10	$ 1.82	$ 1.49
Assuming dilution	$ 2.10	$ 1.81	$ 1.48
FPL [Member]
OPERATING REVENUES	$ 17,282	$ 14,102	$ 13,060
OPERATING EXPENSES
Fuel, purchased power and interchange	5,688	3,956	3,060
Other operations and maintenance	1,857	1,831	1,890
Depreciation and amortization	2,695	2,266	2,526
Taxes other than income taxes and other – net	1,748	1,533	1,464
Total operating expenses – net	11,988	9,586	8,940
OPERATING INCOME	5,294	4,516	4,120
OTHER INCOME (DEDUCTIONS)
Interest Expense	(768)	(615)	(641)
Allowance for equity funds used during construction	105	132	87
Other – net	17	11	2
Total other income (deductions) – net	(646)	(472)	(552)
INCOME BEFORE INCOME TAXES	4,648	4,044	3,568
INCOME TAXES	947	838	678
NET INCOME	$ 3,701	$ 3,206	$ 2,890	[1]
[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, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 3,246	$ 2,827	$ 2,369
Reclassification of unrealized losses on cash flow hedges from accumulated other comprehensive income (loss) to net income	6	6	12
Net unrealized gains (losses) on securities still held	(84)	(11)	12
Reclassification from accumulated other comprehensive income (loss) to net income	10	(4)	(3)
Defined benefit pension and other benefits plans:
Net unrealized gain (loss) and unrecognized prior service benefit (cost)	(133)	95	37
Reclassification from accumulated other comprehensive income (loss) to net income	7	5	2
Net unrealized gains (losses) on foreign currency translation	(44)	(1)	13
Other comprehensive income related to equity method investee	1	1	1
Total other comprehensive income (loss), net of tax	(237)	91	74
IMPACT OF DISPOSAL OF A BUSINESS	0	0	10
COMPREHENSIVE INCOME	3,009	2,918	2,453
COMPREHENSIVE LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	920	747	543
COMPREHENSIVE INCOME ATTRIBUTABLE TO NEE	$ 3,929	$ 3,665	$ 2,996

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Comprehensive Income [Abstract]
Reclassification of unrealized losses on cash flow hedges from accumulated other comprehensive income (loss) to net income, tax expense (benefit)	$ (2)	$ (2)	$ (4)
Net unrealized gains (losses) on securities still held, tax expense (benefit)	(29)	(4)	4
Reclassification from accumulated other comprehensive income (loss) to net income, tax expense (benefit)	(3)	2	1
Net gain (loss) and prior service benefit (cost), tax expense (benefit)	(41)	30	11
Reclassification from accumulated other comprehensive income (loss) to net income, tax expense (benefit)	(2)	(1)	(1)
Other comprehensive income (loss) related to equity method investee, tax expense (benefit)	$ 0	$ 1	1
Impact on Disposal, Tax			$ (19)

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 1,601	$ 639
Customer receivables, net	4,349	3,378
Other receivables	744	730
Materials, supplies and fuel inventory	1,934	1,561
Regulatory assets	2,165	1,125
Derivatives	1,590	689
Other	1,107	1,166
Total current assets	13,490	9,288
Other assets:
Property, plant and equipment – net	111,059	99,348
Special use funds	7,496	8,922
Investment in equity method investees	6,582	6,159
Prepaid benefit costs	1,832	2,243
Regulatory assets	5,992	4,578
Derivatives	1,935	1,135
Goodwill	4,854	4,844
Other	5,695	4,395
Total other assets	145,445	131,624
TOTAL ASSETS	158,935	140,912
Current liabilities:
Commercial paper	1,709	1,382
Other short-term debt	1,368	700
Current portion of long-term debt	6,633	1,785
Accounts payable	8,312	6,935
Customer deposits	560	485
Accrued interest and taxes	719	525
Derivatives	2,102	1,263
Accrued construction-related expenditures	1,760	1,378
Regulatory liabilities	350	289
Other	3,182	2,695
Total current liabilities	26,695	17,437
Other liabilities and deferred credits:
Long-term debt	55,256	50,960
Asset retirement obligations	3,245	3,082
Deferred income taxes	9,072	8,310
Regulatory liabilities	9,626	11,273
Derivatives	2,909	1,713
Other	2,696	2,468
Total other liabilities and deferred credits	82,804	77,806
TOTAL LIABILITIES	109,499	95,243
COMMITMENTS AND CONTINGENCIES
REDEEMABLE NONCONTROLLING INTERESTS – VIEs	1,110	245
EQUITY
Common stock	20	20
Additional paid-in capital	12,720	11,271
Retained earnings	26,707	25,911
Accumulated other comprehensive loss	(218)	0
Total common shareholders' equity	39,229	37,202
Noncontrolling interests	9,097	8,222
TOTAL EQUITY	48,326	45,424
TOTAL LIABILITIES, REDEEMABLE NONCONTROLLING INTERESTS AND EQUITY	158,935	140,912
FPL [Member]
Current assets:
Cash and cash equivalents	25	55
Customer receivables, net	1,739	1,297
Other receivables	332	350
Materials, supplies and fuel inventory	1,159	963
Regulatory assets	2,155	1,111
Derivatives	19	13
Other	143	142
Total current assets	5,553	3,918
Other assets:
Electric utility plant and other property – net	64,693	58,227
Special use funds	5,221	6,158
Prepaid benefit costs	1,732	1,657
Regulatory assets	5,484	4,343
Derivatives	10
Goodwill	2,989	2,989
Other	887	775
Total other assets	81,006	74,149
TOTAL ASSETS	86,559	78,067
Current liabilities:
Commercial paper	1,709	1,382
Other short-term debt	200	200
Current portion of long-term debt	1,547	536
Accounts payable	1,377	1,318
Customer deposits	543	478
Accrued interest and taxes	362	322
Derivatives	12	9
Accrued construction-related expenditures	559	601
Regulatory liabilities	349	278
Other	1,197	643
Total current liabilities	7,843	5,758
Other liabilities and deferred credits:
Long-term debt	19,455	17,974
Asset retirement obligations	2,108	2,049
Deferred income taxes	8,376	7,137
Regulatory liabilities	9,458	11,053
Derivatives	1	1
Other	399	502
Total other liabilities and deferred credits	39,796	38,715
TOTAL LIABILITIES	47,639	44,473
COMMITMENTS AND CONTINGENCIES
EQUITY
Common stock	1,373	1,373
Additional paid-in capital	23,561	19,936
Retained earnings	13,986	12,285
TOTAL EQUITY	38,920	33,594
TOTAL LIABILITIES, REDEEMABLE NONCONTROLLING INTERESTS AND EQUITY	$ 86,559	$ 78,067

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Customer receivables, net of allowances	$ 54	$ 35
Property, plant and equipment – net	111,059	99,348
Current portion of long-term debt	6,633	1,785
Accounts payable	8,312	6,935
Long-term debt	$ 55,256	$ 50,960
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)	1,987,000,000	1,963,000,000
Variable Interest Entity, Primary Beneficiary [Member]
Property, plant and equipment – net	$ 22,927	$ 20,521
Current portion of long-term debt	61	58
Accounts payable	1,250	752
Long-term debt	1,108	1,125
Noncontrolling Interest in Variable Interest Entity	9,092	8,217
FPL [Member]
Customer receivables, net of allowances	7	11
Current portion of long-term debt	1,547	536
Accounts payable	1,377	1,318
Long-term debt	$ 19,455	$ 17,974
Common stock, par value (usd per share)	$ 0	$ 0
Common stock, authorized (in shares)	1,000	1,000
Common stock, issued (in shares)	1,000	1,000
Common stock, outstanding (in shares)	1,000	1,000

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	$ 3,246	$ 2,827	$ 2,369
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	4,503	3,924	4,052
Nuclear fuel and other amortization	287	290	263
Unrealized losses on marked to market derivative contracts – net	1,378	2,005	533
Unrealized losses (gains) on equity securities held in NEER's nuclear decommissioning funds – net	461	(267)	(163)
Foreign currency transaction losses (gains)	(104)	(94)	45
Deferred income taxes	534	436	(78)
Cost recovery clauses and franchise fees	(1,465)	(599)	(121)
Equity in losses (earnings) of equity method investees	(203)	(666)	1,351
Distributions of earnings from equity method investees	541	526	456
Gains on disposal of businesses, assets and investments – net	(602)	(146)	(403)
Recoverable storm-related costs	(811)	(138)	(69)
Other – net	85	(59)	352
Changes in operating assets and liabilities:
Current assets	(1,340)	(1,267)	(364)
Noncurrent assets	(89)	(324)	(234)
Current liabilities	1,702	1,053	(6)
Noncurrent liabilities	139	52	0
Net cash provided by operating activities	8,262	7,553	7,983
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL	(9,067)	(7,408)	(7,489)
Independent power and other investments of NEER	(9,541)	(8,247)	(6,851)
Nuclear fuel purchases	(223)	(275)	(245)
Other capital expenditures	(452)	(147)	(25)
Sale of independent power and other investments of NEER	1,564	2,761	1,012
Proceeds from sale or maturity of securities in special use funds and other investments	3,857	4,995	3,916
Purchases of securities in special use funds and other investments	(4,586)	(5,310)	(4,100)
Other – net	89	40	83
Net cash used in investing activities	(18,359)	(13,591)	(13,699)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt, including premiums and discounts	13,856	16,683	12,404
Retirements of long-term debt	(4,525)	(9,594)	(6,103)
Proceeds from differential membership investors	4,158	2,779	3,522
Net change in commercial paper	327	(169)	(965)
Proceeds from other short-term debt	1,755	0	2,158
Repayments of other short-term debt	(1,125)	(257)	(2,100)
Payments from (to) related parties under a cash sweep and credit support agreement – net	240	47	(2)
Issuances of common stock/equity units – net	1,460	14
Payments of common stock/equity units - net			(92)
Proceeds from sale of noncontrolling interests	0	65	501
Dividends on common stock	(3,352)	(3,024)	(2,743)
Other – net	(565)	(737)	(406)
Net cash provided by financing activities	12,229	5,807	6,174
Effects of currency translation on cash, cash equivalents and restricted cash	(7)	1	(20)
Net increase (decrease) in cash, cash equivalents and restricted cash	2,125	(230)	438
Cash, cash equivalents and restricted cash at beginning of year	1,316	1,546	1,108
Cash, cash equivalents and restricted cash at end of year	3,441	1,316	1,546
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)	1,375	1,323	1,432
Cash paid (received) for income taxes – net	(32)	(69)	235
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	6,005	4,995	4,445
Decrease in property, plant and equipment - net and contract liabilities	668	155	0
Right-of-Use Asset Obtained in Exchange for Finance Lease Liability	204	120	90
Increase in property, plant and equipment related to an acquisition	0	0	68
Decrease in joint venture investments related to an acquisition	0	0	145
FPL [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	3,701	3,206	2,890	[1]
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	2,695	2,266	2,526
Nuclear fuel and other amortization	177	174	167
Deferred income taxes	942	752	629
Cost recovery clauses and franchise fees	(1,465)	(599)	(121)
Recoverable storm-related costs	(811)	(138)	(69)
Other – net	16	(157)	35
Changes in operating assets and liabilities:
Current assets	(534)	(49)	(164)
Noncurrent assets	(73)	(114)	(77)
Current liabilities	175	20	31
Noncurrent liabilities	71	(3)	(31)
Net cash provided by operating activities	4,894	5,358	5,816
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(9,067)	(7,411)	(7,476)
Nuclear fuel purchases	(118)	(159)	(203)
Proceeds from sale or maturity of securities in special use funds and other investments	2,437	3,308	2,488
Purchases of securities in special use funds and other investments	(2,607)	(3,394)	(2,567)
Other – net	(3)	15	65
Net cash used in investing activities	(9,358)	(7,641)	(7,693)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt, including premiums and discounts	2,942	2,588	3,003
Retirements of long-term debt	(441)	(1,304)	(1,603)
Net change in commercial paper	327	(169)	(123)
Capital contributions from NEE	3,625	1,700	2,750
Dividends on common stock	(2,000)	(540)	(2,210)
Other – net	(39)	(44)	(44)
Net cash provided by financing activities	4,414	2,231	1,773
Net increase (decrease) in cash, cash equivalents and restricted cash	(50)	(52)	(104)
Cash, cash equivalents and restricted cash at beginning of year	108	160	264
Cash, cash equivalents and restricted cash at end of year	58	108	160
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)	707	586	620
Cash paid (received) for income taxes – net	22	(1)	105
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	$ 1,024	$ 1,107	$ 698
[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]	Accumulated Other Comprehensive Income (Loss) [Member]	Retained Earnings [Member]	Retained Earnings [Member] Cumulative Effect, Period of Adoption, Adjustment [Member]	[1]	Total common Shareholders' Equity [Member]	Total common Shareholders' Equity [Member] Cumulative Effect, Period of Adoption, Adjustment [Member]	[1]	Noncontrolling Interest [Member]	FPL [Member]		FPL [Member] Common Stock [Member]	FPL [Member] Additional Paid-in Capital [Member]	FPL [Member] Retained Earnings [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Redeemable non-controlling interest, beginning balance		$ 487
Balances (in shares) at Dec. 31, 2019			1,956,000,000
Beginning Balance at Dec. 31, 2019		41,360	$ 20	$ 11,955	$ (169)	$ 25,199	$ (11)		$ 37,005	$ (11)		$ 4,355	$ 25,797		$ 1,373	$ 15,485	$ 8,939
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)		2,369				2,919			2,919			(546)	2,890	[2]
Issuances of common stock, net of issuance cost (in shares)			0
Issuances of common stock/equity units – net				(92)					(92)
Share-based payment activity				153					153
Share-based payment activity (in shares)			4,000,000
Dividends on common stock	[3]					(2,743)			(2,743)
Other comprehensive income (loss)		74			67				67			7
Impact of disposal of a business					10				10
Premium on equity units				(587)					(587)
Other differential membership interest activity				(36)					(36)			3,809
Sale of noncontrolling interests				(169)					(169)			689
Capital contributions from NEE													2,750			2,750
Dividends to NEE		2,743											2,210				(2,210)
Other (in shares)			0
Other			$ 0	(2)	0	(1)			(3)			102				1	0
Ending Balance at Dec. 31, 2020		44,929	$ 20	11,222	(92)	25,363			36,513			8,416	29,228		1,373	18,236	9,619
Balance (in shares) at Dec. 31, 2020			1,960,000,000
Increase (Decrease) in Temporary Equity [Roll Forward]
Net income (loss)		(4)
Other differential membership interest activity		(483)
Other		0
Redeemable non-controlling interest, beginning balance at Dec. 31, 2020		0
Increase (Decrease) in Temporary Equity [Roll Forward]
Redeemable non-controlling interest, beginning balance		0
Net income (loss)		2,827				3,573			3,573			(748)	3,206				3,206	[2]
Share-based payment activity				132					132
Share-based payment activity (in shares)			3,000,000
Dividends on common stock	[3]					(3,024)			(3,024)
Other comprehensive income (loss)		91			92				92			(1)
Other differential membership interest activity	[4]			(26)					(26)			363
Capital contributions from NEE													1,700			1,700
Dividends to NEE		3,024											540				(540)
Other			$ 0	(57)	0	(1)			(58)			192
Ending Balance at Dec. 31, 2021		$ 45,424	$ 20	11,271	0	25,911			37,202			8,222	$ 33,594		1,373	19,936	12,285
Balance (in shares) at Dec. 31, 2021		1,963,000,000	1,963,000,000										1,000
Increase (Decrease) in Temporary Equity [Roll Forward]
Net income (loss)		$ 2
Other differential membership interest activity	[4]	243
Redeemable non-controlling interest, beginning balance at Dec. 31, 2021		245
Increase (Decrease) in Temporary Equity [Roll Forward]
Redeemable non-controlling interest, beginning balance		245
Net income (loss)		3,246				4,147			4,147			(909)	$ 3,701				3,701	[2]
Issuances of common stock, net of issuance cost (in shares)			22,000,000
Issuances of common stock/equity units – net				1,446					1,446
Share-based payment activity				171					171
Share-based payment activity (in shares)			2,000,000
Dividends on common stock	[3]					(3,352)			(3,352)
Other comprehensive income (loss)		(237)			(218)				(218)			(19)
Premium on equity units				(127)					(127)
Other differential membership interest activity				(39)					(39)			3,131
Capital contributions from NEE													3,625			3,625
Dividends to NEE		3,352											2,000				(2,000)
Disposal of subsidiaries with noncontrolling interests	[4]											(1,494)
Other				(2)		1			(1)			166
Ending Balance at Dec. 31, 2022		$ 48,326	$ 20	$ 12,720	$ (218)	$ 26,707			$ 39,229			$ 9,097	$ 38,920		$ 1,373	$ 23,561	$ 13,986
Balance (in shares) at Dec. 31, 2022		1,987,000,000	1,987,000,000										1,000
Increase (Decrease) in Temporary Equity [Roll Forward]
Net income (loss)		$ 8
Other differential membership interest activity		859
Other		(2)
Redeemable non-controlling interest, beginning balance at Dec. 31, 2022		1,110
Increase (Decrease) in Temporary Equity [Roll Forward]
Redeemable non-controlling interest, beginning balance		$ 1,110
[1]See Note 1 – Measurement of Credit Losses on Financial Instruments.[2]FPL's comprehensive income is the same as reported net income.[3]Dividends per share were $1.70, $1.54 and $1.40 for the years ended December 31, 2022, 2021 and 2020, respectively[4]See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

CONSOLIDATED STATEMENTS OF CO_3

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Stockholders' Equity [Abstract]
Common stock dividends (in dollars per share)	$ 1.70	$ 1.54	$ 1.40

Summary of Significant Accounti

Summary of Significant Accounting and Reporting Policies	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Summary of Significant Accounting and Reporting Policies	Summary of Significant Accounting and Reporting Policies Basis of Presentation – The operations of NextEra Energy, Inc. (NEE) are conducted primarily through Florida Power & Light Company (FPL), a wholly owned subsidiary, and NextEra Energy Resources, LLC (NextEra Energy Resources) and NextEra Energy Transmission, LLC (NEET) (collectively, NEER), wholly owned indirect subsidiaries that are combined for segment reporting purposes. On January 1, 2021, FPL and Gulf Power Company merged, with FPL as the surviving entity. However during 2021, FPL continued to be regulated as two separate ratemaking entities in the former service areas of FPL and Gulf Power. Effective January 1, 2022, FPL became regulated as one electric ratemaking entity with new unified rates and tariffs, and also became one reportable segment of NEE (see Rate Regulation – Base Rates Effective January 2022 through December 2025 below). As a result, the previous segments known as the FPL segment and Gulf Power are no longer separate reportable segments. See Note 16. FPL's principal business is a rate-regulated electric utility which supplies electric service to approximately 5.8 million customer accounts throughout most of the east and lower west coasts of Florida and eight counties throughout northwest Florida. NEER invests in independent power projects through both controlled and consolidated entities and noncontrolling owner ship interests in joint ventures. NEER participates in natural gas, natural gas liquids and oil production primarily through operating and non-operating ownership interests and in pipeline infrastructure through either wholly owned subsidiaries or noncontrolling or joint venture interests. NEER also invests in rate-regulated transmission facilities and transmission lines that connect its electric generation facilities to the electric grid through controlled and consolidated entities. The consolidated financial statements of NEE and FPL include the accounts of their respective controlled subsidiaries. They also include NEE's and FPL's share of the undivided interest in certain assets, liabilities, revenues and expenses. Amounts representing NEE's interest in entities it does not control, but over which it exercises significant influence, are included in investment in equity method investees; the earnings/losses of these entities is included in equity in earnings (losses) of equity method investees. Intercompany balances and transactions have been eliminated in consolidation. Certain amounts included in prior years' consolidated financial statements have been reclassified to conform to the current year's presentation. The preparation of financial statements requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of c ontingent assets and liabilities. Actual results could differ from those estimates. NextEra Energy Partners, LP (NEP) was formed in 2014 to acquire, manage and own contracted clean energy projects with stable long-term cash flows through a limited partner interest in NextEra Energy Operating Partners, LP (NEP OpCo). NEP owns or has an ownership interest in a portfolio of wind, solar and solar plus battery storage projects and long-term contracted natural gas pipelines. NEE owns a noncontrolling interest in NEP, accounts for its ownership interest in NEP as an equity method investment with its earnings/losses from NEP as equity in earnings (losses) of equity method investees and accounts for NextEra Energy Resources' project sales to NEP as third-party sales in its consolidated financial statements. NEER operates essentially all of the energy projects owned by NEP and provides services to NEP under various related party operations and maintenance, administrative and management services agreements. Operating Revenues – FPL and NEER generate substantially all of NEE’s operating revenues, which primarily include revenues from contracts with customers as further discussed in Note 2 , as well as, at NEER, derivative and lease transactions. FPL's operating revenues include amounts resulting from base rates, cost recovery clauses (see Rate Regulation below), franchise fees, gross receipts taxes and surcharges related to storms (see Storm Funds, Storm Reserves and Storm Cost Recovery below). Franchise fees and gross receipts taxes are imposed on FPL; however, the Florida Public Service Commission (FPSC) allows FPL to include in the amounts charged to customers the amount of the gross receipts tax for all customers and the franchise fee for those customers located in the jurisdiction that imposes the amount. Accordingly, FPL's franchise fees and gross receipts taxes are reported gross in operating revenues and taxes other than income taxes and other in NEE's and FPL's consolidated statements of income and were approximately $1,035 million, $852 million and $800 million in 2022, 2021 and 2020, respectively. FPL also collects municipal utility taxes which are reported gross in customer receivables and accounts payable on NEE's and FPL's consolidated balance sheets. Certain NEER commodity contracts for the purchase and sale of power that meet the definition of a derivative are recorded at fair value with subsequent changes in fair value recognized as revenue. See Energy Trading below and Note 3. Rate Regulation – FPL, the most significant of NEE's rate-regulated subsidiaries, is subject to rate regulation by the FPSC and the Federal Energy Regulatory Commission (FERC). Its rates are designed to recover the cost of providing service to its customers including a reasonable rate of return on invested capital. As a result of this cost-based regulation, FPL follows the accounting guidance that allows regulators to create assets and impose liabilities that would not be recorded by non-rate regulated entities. Regulatory assets and liabilities represent probable future revenues that will be recovered from or refunded to customers through the ratemaking process. NEE's and FPL's regulatory assets and liabilities are as follows: NEE FPL December 31, December 31, 2022 2021 2022 2021 (millions) Regulatory assets: Current: Early retirement of generation facilities and transmission assets (a) $ 145 $ 140 $ 145 $ 140 Acquisition of purchased power agreements (b) 141 141 141 141 Deferred clause and franchise expenses 919 (c) 698 919 (c) 698 Storm restoration costs 911 (d) 92 911 (d) 92 Other 49 54 39 40 Total $ 2,165 $ 1,125 $ 2,155 $ 1,111 Noncurrent: Early retirement of generation facilities and transmission assets (a) $ 2,026 $ 2,233 $ 2,026 $ 2,233 Acquisition of purchased power agreements (b) 191 332 191 332 Deferred clause expenses 1,227 (c) 17 1,227 (c) 17 Storm restoration costs 326 (d) 150 326 (d) 150 Accrued asset removal costs (e) 532 263 532 263 Other 1,690 1,583 1,182 1,348 Total $ 5,992 $ 4,578 $ 5,484 $ 4,343 Regulatory liabilities: Current: Deferred clause revenues $ 339 $ 274 $ 339 $ 274 Other 11 15 10 4 Total $ 350 $ 289 $ 349 $ 278 Noncurrent: Asset retirement obligation regulatory expense difference $ 3,323 $ 4,290 $ 3,323 $ 4,290 Accrued asset removal costs (e) 658 782 623 752 Deferred taxes 4,233 4,561 4,129 4,457 Other 1,412 1,640 1,383 1,554 Total $ 9,626 $ 11,273 $ 9,458 $ 11,053 ______________________ (a) The majority of these regulatory assets are being amortized over 20 years. (b) The majority of these regulatory assets are being amortized over approximately 9 years. (c) The majority of these regulatory assets are expected to be amortized over 21 months beginning April 2023. See below regarding the 2022 fuel under-recovery. (d) The majority of these regulatory assets are expected to be amortized over 12 months beginning April 2023. See Storm Funds, Storm Reserves and Storm Cost Recovery below. (e) See Electric Plant, Depreciation and Amortization below. Cost recovery clauses, which are designed to permit full recovery of certain costs and provide a return on certain assets allowed to be recovered through various clauses, include substantially all fuel, purchased power and interchange expense, costs associated with an FPSC-approved transmission and distribution storm protection plan, certain costs associated with the acquisition and retirement of several electric generation facilities, certain construction-related costs for certain of FPL's solar generation facilities, and conservation and certain environmental-related costs. Revenues from cost recovery clauses are recorded when billed; FPL achieves matching of costs and related revenues by deferring the net under-recovery or over-recovery. Any under-recovered costs or over-recovered revenues are collected from or returned to customers in subsequent periods. In January 2023, FPL filed a petition with the FPSC requesting recovery of its 2022 fuel under-recovery of approximately $2.1 billion (included in current deferred clause and franchise expenses and noncurrent deferred clause expenses above) over 21 months beginning April 2023. As a result of natural gas prices currently being lower than originally projected for 2023, FPL also requested a $1.0 billion mid-course correction to reduce the 2023 levelized fuel charges to customers that would go into effect beginning April 2023. An FPSC decision is expected in March 2023. If FPL were no longer subject to cost-based rate regulation, the existing regulatory assets and liabilities would be written off unless regulators specify an alternative means of recovery or refund. In addition, the FPSC has the authority to disallow recovery of costs that it considers excessive or imprudently incurred. The continued applicability of regulatory accounting is assessed at each reporting period. Regulatory assets and liabilities are discussed within various subsections below. Base Rates Effective January 2022 through December 2025 – In December 2021, the FPSC issued a final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2021 rate agreement). Key elements of the 2021 rate agreement, which is effective from January 2022 through at least December 2025, include, among other things, the following: • New retail base rates and charges were established for the combined utility system (including the former Gulf Power Company service area) resulting in the following increases in annualized retail base revenues: ◦ $692 million beginning January 1, 2022, and ◦ $560 million beginning January 1, 2023. • In addition, FPL is eligible to receive, subject to conditions specified in the 2021 rate agreement, base rate increases associated with the addition of up to 894 megawatts (MW) annually of new solar generation (through a Solar Base Rate Adjustment (SoBRA) mechanism) in each of 2024 and 2025, and may carry forward any unused MW in 2024 to 2025. FPL has agreed to an installed cost cap of $1,250 per kilowatt and will be required to demonstrate that these proposed solar facilities are cost effective. • FPL's authorized regulatory return on common equity (ROE) was 10.60%, with a range of 9.70% to 11.70%. However, in the event the average 30-year U.S. Treasury rate was 2.49% or greater over a consecutive six-month period, FPL was authorized to increase the regulatory ROE to 10.80% with a range of 9.80% to 11.80%. During August 2022, this provision was triggered and effective September 1, 2022, FPL's authorized regulatory ROE and ROE range were increased. The revised authorized regulatory ROE will have only a minimal impact to base rates. If FPL's earned regulatory ROE falls below 9.80%, FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.80%, any party with standing may seek a review of FPL's retail base rates. • Subject to certain conditions, FPL may amortize, over the term of the 2021 rate agreement, up to $1.45 billion of depreciation reserve surplus, provided that in any year of the 2021 rate agreement FPL must amortize at least enough reserve amount to maintain its minimum authorized regulatory ROE and also may not amortize any reserve amount that would result in an earned regulatory ROE in excess of its maximum authorized regulatory ROE. • FPL is authorized to expand SolarTogether™, a voluntary community solar program that gives FPL electric customers an opportunity to participate directly in the expansion of solar energy where participants pay a fixed monthly subscription charge and receive credits on their related monthly customer bill, by constructing an additional 1,788 MW of solar generation from 2022 through 2025, such that the total capacity of SolarTogether™ would be 3,278 MW. • Future storm restoration costs would be recoverable on an interim basis beginning 60 days from the filing of a cost recovery petition, but capped at an amount that produces a surcharge of no more than $4 for every 1,000 kilowatt-hour (kWh) of usage on residential bills during the first 12 months of cost recovery. Any additional costs would be eligible for recovery in subsequent years. If storm restoration costs exceed $800 million in any given calendar year, FPL may request an increase to the $4 surcharge. See Storm Funds, Storm Reserves and Storm Cost Recovery below. • If federal or state permanent corporate income tax changes become effective during the term of the 2021 rate agreement, FPL will prospectively adjust base rates after a review by the FPSC. As a result of the enactment of the Inflation Reduction Act (IRA) (see Note 5), FPL's customers are expected to save approximately $400 million over the remaining term of the 2021 rate agreement which includes a $36 million one-time refund made in January 2023. On February 8, 2023, the Florida Supreme Court heard oral argument on the appeal of the FPSC's final order regarding the 2021 rate agreement by Floridians Against Increased Rates, Inc. and, as a group, Florida Rising, Inc., Environmental Confederation of Southwest Florida, Inc. and League of United Latin American Citizens of Florida (collectively, the appellants). The appellants argue that the FPSC lacked authority to approve certain aspects of FPL's 2021 rate agreement, that the final order fails to address certain contested issues and that certain of the FPSC's findings in its final order were not adequately analyzed or supported by evidence and have requested that the final order be reversed or remanded. FPL believes that the FPSC’s decision should not be reversed or remanded by the Florida Supreme Court, because, among other things, the FPSC acted within its statutory authority in approving the 2021 rate agreement and the FPSC’s public-interest findings are supported by competent, substantial evidence in the record. A ruling by the Florida Supreme Court is pending. Base Rates Effective January 2017 through December 2021 – From January 2017 to December 2021, FPL operated under a base rate agreement (2016 rate agreement) that provided for, among other things, a regulatory ROE of 10.55%, with a range of 9.60% to 11.60% and, subject to certain conditions, the right to reduce depreciation expense up to $1.25 billion (reserve), provided that in any year of the 2016 rate agreement FPL was required to amortize enough reserve to maintain an earned regulatory ROE within the range of 9.60% to 11.60%. Electric Plant, Depreciation and Amortization – The cost of additions to units of property of FPL and NEER is added to electric plant in service and other property. In accordance with regulatory accounting, the cost of FPL's units of utility property retired, less estimated net salvage value, is charged to accumulated depreciation. Maintenance and repairs of property as well as replacements and renewals of items determined to be less than units of utility property are charged to other operations and maintenance (O&M) expenses. The American Recovery and Reinvestment Act of 2009, as amended, provided for an option to elect a cash grant (convertible investment tax credits (ITCs)) for certain renewable energy property (renewable property). Convertible ITCs are recorded as a reduction in property, plant and equipment on NEE's and FPL's consolidated balance sheets and are amortized as a reduction to depreciation and amortization expense over the estimated life of the related property. At December 31, 2022 and 2021, convertible ITCs, net of amortization, were approximately $693 million ($111 million at FPL) and $755 million ($116 million at FPL). Depreciation of FPL's electric property is provided on a straight-line basis, primarily over its average remaining useful life. FPL includes in depreciation expense a provision for electric generation plant dismantlement, interim asset removal costs, accretion related to asset retirement obligations (see Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below) and storm recovery amortization. For substantially all of FPL's property, depreciation studies are performed periodically and filed with the FPSC which result in updated depreciation rates. As part of the 2021 rate agreement, the FPSC approved new unified depreciation rates which became effective January 1, 2022. Reserve amortization is recorded as either an increase or decrease to accrued asset removal costs which is reflected in noncurrent regulatory assets on NEE's and FPL's consolidated balance sheets. FPL files a twelve-month forecast with the FPSC each year which contains a regulatory ROE intended to be earned based on the best information FPL has at that time assuming normal weather. This forecast establishes a targeted regulatory ROE. In order to earn the targeted regulatory ROE in each reporting period subject to the conditions of the effective rate agreement, reserve amortization is calculated using a trailing thirteen-month average of retail rate base and capital structure in conjunction with the trailing twelve months regulatory retail base net operating income, which primarily includes the retail base portion of base and other revenues, net of O&M, depreciation and amortization, interest and tax expenses. In general, the net impact of these income statement line items is adjusted, in part, by reserve amortization or its reversal to earn the targeted regulatory ROE. See Rate Regulation – Base Rates Effective January 2022 through December 2025 above. NEER's electric plant in service and other property less salvage value, if any, are depreciated primarily using the straight-line method over their estimated useful lives. NEER reviews the estimated useful lives of its fixed assets on an ongoing basis. NEER's oil and gas production assets are accounted for under the successful efforts method. Depletion expenses for the acquisition of reserve rights and development costs are recognized using the unit of production method. Nuclear Fuel – FPL and NEER have several contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel. See Note 15 – Contracts. FPL's and NEER's nuclear fuel costs are charged to fuel expense on a unit of production method. Construction Activity – Allowance for funds used during construction (AFUDC) is a noncash item which represents the allowed cost of capital, including an ROE, used to finance construction projects. FPL records the portion of AFUDC attributable to borrowed funds as a reduction of interest expense and the remainder as other income. FPSC rules limit the recording of AFUDC to projects that have an estimated cost in excess of 0.5% prior to 2021 and 0.4% beginning in 2021 of a utility's plant in service balance and require more than one year to complete. FPSC rules allow construction projects below the applicable threshold as a component of rate base. FPL's construction work in progress includes construction materials, progress payments on major equipment contracts, engineering costs, AFUDC and other costs directly associated with the construction of various projects. Upon completion of the projects, these costs are transferred to electric utility plant in service and other property. Capitalized costs associated with construction activities are charged to O&M expenses when recoverability is no longer probable. NEER capitalizes project development costs once it is probable that such costs will be realized through the ultimate construction of the related asset or sale of development rights. At December 31, 2022 and 2021, NEER's capitalized development costs totaled approximately $1,027 million and $831 million, respectively, which are included in noncurrent other assets on NEE's consolidated balance sheets. These costs include land rights and other third-party costs directly associated with the development of a new project. Upon commencement of construction, these costs either are transferred to construction work in progress or remain in other assets, depending upon the nature of the cost. Capitalized development costs are charged to O&M expenses when it is probable that these costs will not be realized. NEER's construction work in progress includes construction materials, progress payments on major equipment contracts, third-party engineering costs, capitalized interest and other costs directly associated with the construction and development of various projects. Interest expense allocated from NextEra Energy Capital Holdings, Inc. (NEECH) to NEER is based on a deemed capital structure of 70% debt and differential membership interests sold by NextEra Energy Resources' subsidiaries. Upon commencement of project operation, costs associated with construction work in progress are transferred to electric plant in service and other property. Asset Retirement Obligations – NEE and FPL each account for asset retirement obligations and conditional asset retirement obligations (collectively, AROs) under accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated, with the offsetting associated asset retirement costs capitalized as part of the carrying amount of the long-lived assets. NEE's AROs relate primarily to decommissioning obligations of FPL's and NEER's nuclear units and to obligations for the dismantlement of certain of NEER's wind and solar facilities. See Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below and Note 11. For NEE's rate-regulated operations, including FPL, the asset retirement cost is allocated to a regulatory liability or regulatory asset using a systematic and rational method over the asset's estimated useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the ARO and a decrease in the regulatory liability or regulatory asset. Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the ARO and asset retirement cost, or regulatory liability when asset retirement cost is depleted. For NEE's non-rate regulated operations, the asset retirement cost is allocated to expense using a systematic and rational method over the asset's estimated useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense, which is included in depreciation and amortization expense in NEE's consolidated statements of income. Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the asset retirement cost, or income when asset retirement cost is depleted. Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs – For ratemaking purposes, FPL accrues for the cost of end of life retirement and disposal of its nuclear and other generation plants over the expected service life of each unit based on nuclear decommissioning and other generation dismantlement studies periodically filed with the FPSC. In addition, FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC. As approved by the FPSC, FPL previously suspended its annual decommissioning accrual. Any differences between expense recognized for financial reporting purposes and the amount recovered through rates are reported as a regulatory asset or liability in accordance with regulatory accounting. See Rate Regulation, Electric Plant, Depreciation and Amortization, and Asset Retirement Obligations above and Note 11. Nuclear decommissioning studies are performed at least every five years and are filed with the FPSC for approval. FPL filed updated nuclear decommissioning studies with the FPSC in December 2020. These studies reflect, among other things, the expiration dates of the operating licenses for FPL's nuclear units at the time of the studies. The 2020 studies provide for the dismantlement of Turkey Point Units Nos. 3 and 4 following the end of plant operation with decommissioning activities commencing in 2052 and 2053, respectively, however, in 2022, the U.S. Nuclear Regulatory Commission (NRC) amended Turkey Point Units Nos. 3 and 4 license renewals by removing the 20 additional years of operation reflected in the studies. FPL filed a site-specific environmental impact statement with the NRC related to the previously approved 20-year renewal application for both Turkey Point operating licenses. Approval of the additional 20 years of operations is pending. The studies filed in 2020 also provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the dismantlement of St. Lucie Unit No. 2 in 2043. These studies also assume that FPL will be storing spent fuel on site pending removal to a United States (U.S.) government facility. FPL's portion of the ultimate costs of decommissioning its four nuclear units, including costs associated with spent fuel storage above what is expected to be refunded by the U.S. Department of Energy (DOE) under a spent fuel settlement agreement, is estimated to be approximately $9.6 billion, or $2.5 billion expressed in 2022 dollars. The ultimate costs of decommissioning reflect the applications submitted to the NRC for the extension of Turkey Point Units Nos. 3 and 4 and St. Lucie Units Nos. 1 and 2 licenses for an additional 20 years. Restricted funds for the payment of future expenditures to decommission FPL's nuclear units are included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's and FPL's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily carried at fair value. See Note 4. Fund earnings, consisting of dividends, interest and realized gains and losses, net of taxes, are reinvested in the funds. Fund earnings, as well as any changes in unrealized gains and losses and estimated credit losses on debt securities, are not recognized in income and are reflected as a corresponding offset in the related regulatory asset or liability accounts. FPL does not currently make contributions to the decommissioning funds, other than the reinvestment of fund earnings. During 2022, 2021 and 2020 fund earnings on decommissioning funds were approximately $58 million, $173 million and $132 million, respectively. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. Other generation plant dismantlement studies are performed periodically and are submitted to the FPSC for approval. Previously approved studies were effective from January 1, 2017 through December 2021 and resulted in an annual expense of $26 million which is recorded in depreciation and amortization expense in NEE's and FPL's consolidated statements of income. As part of the 2021 rate agreement, the FPSC approved a new annual expense of $48 million based on FPL's updated dismantlement studies which became effective January 1, 2022. At December 31, 2022, FPL's portion of the ultimate cost to dismantle its other generation units is approximately $2.4 billion, or $1.2 billion expressed in 2022 dollars. NEER's AROs primarily include nuclear decommissioning liabilities for Seabrook Station (Seabrook), Duane Arnold Energy Center (Duane Arnold) and Point Beach Nuclear Power Plant (Point Beach) and dismantlement liabilities for its wind and solar facilities. The liabilities are being accreted using the interest method through the date decommissioning or dismantlement activities are expected to be complete. See Note 11. At December 31, 2022 and 2021, NEER's ARO was approximately $1.2 billion and $1.1 billion, respectively, and was primarily determined using various internal and external data and applying a probability percentage to a variety of scenarios regarding the life of the plant and timing of decommissioning or dismantlement. NEER's portion of the ultimate cost of decommissioning its nuclear plants, including costs associated with spent fuel storage above what is expected to be refunded by the DOE under a spent fuel settlement agreement, is estimated to be approximately $9.5 billion, or $2.0 billion expressed in 2022 dollars. The ultimate cost to dismantle NEER's wind and solar facilities is estimated to be approximately $2.5 billion. Seabrook files a comprehensive nuclear decommissioning study with the New Hampshire Nuclear Decommissioning Financing Committee (NDFC) every four years; the most recent study was filed in 2019. Seabrook's decommissioning funding plan is also subject to annual review by the NDFC. Currently, there are no ongoing decommissioning funding requirements for Seabrook, Duane Arnold and Point Beach, however, the NRC, and in the case of Seabrook, the NDFC, has the authority to require additional funding in the future. NEER's portion of Seabrook's, Duane Arnold's and Point Beach's restricted funds for the payment of future expenditures to decommission these plants is included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily carried at fair value. See Note 4. Market adjustments for debt securities result in a corresponding adjustment to other comprehensive income (OCI), except for estimated credit losses and unrealized losses on debt securities intended or required to be sold prior to recovery of the amortized cost basis, which are recognized in other – net in NEE's consolidated statements of income. Market adjustments for equity securities are recorded in change in unrealized gains (losses) on equity securities held in NEER's nuclear decommissioning funds – net in NEE's consolidated statements of income. Fund earnings, consisting of dividends, interest and realized gains and losses are recognized in income and are reinvested in the funds. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. Major Maintenance Costs – FPL expenses costs associated with planned maintenance for its non-nuclear electric generation plants as incurred. FPL recognizes costs associated with planned major nuclear maintenance in accordance with regulatory treatment. FPL defers nuclear maintenance costs for each nuclear unit’s planned outage to a regulatory asset as the costs are incurred. FPL amortizes the costs to O&M expense using the straight-line method over the period from the end of the current outage to the next planned outage where the respective work scope is performed. NEER uses the deferral method to account for certain planned major maintenance costs. NEER's major maintenance costs for its nuclear generation units and combustion turbines are capitalized (included in noncurrent other assets on NEE's consolidated balance sheets) and amortized to O&M expense using the straight-line method over the period from the end of the current outage to the next planned outage where the respective work scope is performed. Cash Equivalents – Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less. Restricted Cash – At December 31, 2022 and 2021, NEE had approximately $1,840 million ($33 million for FPL) and $677 million ($53 million for FPL), respectively, of restricted cash, which is included in current other assets on NEE's and FPL's consolidated balance sheets. Restricted cash is primarily related to debt service payments and margin cash collateral requirements at NEER and bond proceeds held for construction at FPL. In addition, where offsetting positions exist, re

Revenue from Contracts with Cus

Revenue from Contracts with Customers	12 Months Ended
	Dec. 31, 2022
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 (see Note 3) 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 2022, 2021 and 2020, NEE’s revenue from contracts with customers was approximately $23.0 billion ($17.2 billion at FPL), $18.8 billion ($14.1 billion at FPL) and $17.0 billion ($13.0 billion at FPL), respectively. NEE's and FPL's receivables are primarily associated with revenues earned from contracts with customers, as well as derivative and lease transactions at NEER, and consist of both billed and unbilled amounts, which are recorded in customer receivables and other receivables on NEE's and FPL's consolidated balance sheets. Receivables represent unconditional rights to consideration and reflect the differences in timing of revenue recognition and cash collections. For substantially all of NEE's and FPL's receivables, regardless of the type of revenue transaction from which the receivable originated, customer and counterparty credit risk is managed in the same manner and the terms and conditions of payment are similar. During 2021, NEER did not recognize approximately $180 million of revenue related to reimbursable expenses from a counterparty that were deemed not probable of collection. These reimbursable expenses arose from the impacts of the February 2021 weather event. These determinations were made based on assessments of the counterparty's creditworthiness and NEER's ability to collect. FPL – FPL’s revenues are derived primarily from tariff-based sales that result from providing electricity to retail customers in Florida with no defined contractual term. Electricity sales to retail customers account for approximately 90% of FPL’s 2022 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, 2022 and 2021, FPL's unbilled revenues amounted to approximately $661 million and $583 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, 2022, FPL expects to record approximately $390 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 2023 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 through 2036, certain power purchase agreements with maturity dates through

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2022
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 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 substantially all 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 year ended December 31, 2020, NEE reclassified from AOCI approximately $26 million ($6 million after tax), of which $23 million was reclassified to gains on disposal of businesses/assets – net (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests) with the balance to interest expense, because it became probable that related future transactions being hedged would not occur. At December 31, 2022, 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 $2 million of net losses included in AOCI at December 31, 2022 are expected to be reclassified into earnings within the next 12 months as the principal and/or interest payments are made. Such amounts assume no change in scheduled principal payments. Fair Value Measurements of Derivative Instruments – The fair value of assets and liabilities are determined using either unadjusted quoted prices in active markets (Level 1) or pricing inputs that are observable (Level 2) whenever that information is available and using unobservable inputs (Level 3) to estimate fair value only when relevant observable inputs are not available. NEE and FPL use several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those assets and liabilities that are measured at fair value on a recurring basis. NEE's and FPL's assessment of the significance of any particular input to the fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Non-performance risk, including the consideration of a credit valuation adjustment, is also considered in the determination of fair value for all assets and liabilities measured at fair value. NEE and FPL measure the fair value of commodity contracts using a combination of market and income approaches utilizing prices observed on commodities exchanges and in the OTC markets, or through the use of industry-standard valuation techniques, such as option modeling or discounted cash flows techniques, incorporating both observable and unobservable valuation inputs. The resulting measurements are the best estimate of fair value as represented by the transfer of the asset or liability through an orderly transaction in the marketplace at the measurement date. Most exchange-traded derivative assets and liabilities are valued directly using unadjusted quoted prices. For exchange-traded derivative assets and liabilities where the principal market is deemed to be inactive based on average daily volumes and open interest, the measurement is established using settlement prices from the exchanges, and therefore considered to be valued using other observable inputs. NEE, through its subsidiaries, including FPL, also enters into OTC commodity contract derivatives. The majority of these contracts are transacted at liquid trading points, and the prices for these contracts are verified using quoted prices in active markets from exchanges, brokers or pricing services for similar contracts. NEE, through NEER, also enters into full requirements contracts, which, in most cases, meet the definition of derivatives and are measured at fair value. These contracts typically have one or more inputs that are not observable and are significant to the valuation of the contract. In addition, certain exchange and non-exchange traded derivative options at NEE have one or more significant inputs that are not observable, and are valued using industry-standard option models. In all cases where NEE and FPL use significant unobservable inputs for the valuation of a commodity contract, consideration is given to the assumptions that market participants would use in valuing the asset or liability. The primary input to the valuation models for commodity contracts is the forward commodity curve for the respective instruments. Other inputs include, but are not limited to, assumptions about market liquidity, volatility, correlation and contract duration as more fully described below in Significant Unobservable Inputs Used in Recurring Fair Value Measurements. In instances where the reference markets are deemed to be inactive or do not have transactions for a similar contract, the derivative assets and liabilities may be valued using significant other observable inputs and potentially significant unobservable inputs. In such instances, the valuation for these contracts is established using techniques including extrapolation from or interpolation between actively traded contracts, or estimated basis adjustments from liquid trading points. NEE and FPL regularly evaluate and validate the inputs used to determine fair value by a number of methods, consisting of various market price verification procedures, including the use of pricing services and multiple broker quotes to support the market price of the various commodities. In all cases where there are assumptions and models used to generate inputs for valuing derivative assets and liabilities, the review and verification of the assumptions, models and changes to the models are undertaken by individuals that are independent of those responsible for estimating fair value. NEE uses interest rate contracts and foreign currency contracts to mitigate and adjust interest rate and foreign currency exchange exposure related primarily to certain outstanding and expected future debt issuances and borrowings when deemed appropriate based on market conditions or when required by financing agreements. NEE estimates the fair value of these derivatives using an income approach based on a discounted cash flows valuation technique utilizing the net amount of estimated future cash inflows and outflows related to the agreements. The tables below present NEE's and FPL's gross derivative positions at December 31, 2022 and 2021, 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, 2022 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: NEE: Commodity contracts $ 5,372 $ 7,559 $ 2,094 $ (12,030) $ 2,995 Interest rate contracts $ — $ 583 $ — $ (49) 534 Foreign currency contracts $ — $ — $ — $ (4) (4) Total derivative assets $ 3,525 FPL – commodity contracts $ — $ 11 $ 25 $ (7) $ 29 Liabilities: NEE: Commodity contracts $ 7,185 $ 7,620 $ 2,948 $ (13,010) $ 4,743 Interest rate contracts $ — $ 191 $ — $ (49) 142 Foreign currency contracts $ — $ 130 $ — $ (4) 126 Total derivative liabilities $ 5,011 FPL – commodity contracts $ — $ 4 $ 16 $ (7) $ 13 Net fair value by NEE balance sheet line item: Current derivative assets (b) $ 1,590 Noncurrent derivative assets (c) 1,935 Total derivative assets $ 3,525 Current derivative liabilities (d) $ 2,102 Noncurrent derivative liabilities (e) 2,909 Total derivative liabilities $ 5,011 Net fair value by FPL balance sheet line item: Current other assets $ 19 Noncurrent other assets 10 Total derivative assets $ 29 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 $299 million in margin cash collateral received from counterparties. (c) Reflects the netting of approximately $262 million in margin cash collateral received from counterparties. (d) Reflects the netting of approximately $328 million in margin cash collateral paid to counterparties. (e) Reflects the netting of approximately $1,213 million in margin cash collateral paid to counterparties. December 31, 2021 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: NEE: Commodity contracts $ 1,896 $ 5,082 $ 1,401 $ (6,622) $ 1,757 Interest rate contracts $ — $ 106 $ — $ (30) 76 Foreign currency contracts $ — $ 8 $ — $ (17) (9) Total derivative assets $ 1,824 FPL – commodity contracts $ — $ 3 $ 13 $ (3) $ 13 Liabilities: NEE: Commodity contracts $ 2,571 $ 4,990 $ 1,231 $ (6,594) $ 2,198 Interest rate contracts $ — $ 739 $ — $ (30) 709 Foreign currency contracts $ — $ 86 $ — $ (17) 69 Total derivative liabilities $ 2,976 FPL – commodity contracts $ — $ 8 $ 5 $ (3) $ 10 Net fair value by NEE balance sheet line item: Current derivative assets (b) $ 689 Noncurrent derivative assets (c) 1,135 Total derivative assets $ 1,824 Current derivative liabilities (d) $ 1,263 Noncurrent derivative liabilities (e) 1,713 Total derivative liabilities $ 2,976 Net fair value by FPL balance sheet line item: Current other assets $ 13 Current other liabilities $ 9 Noncurrent other liabilities 1 Total derivative liabilities $ 10 ______________________ (a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the consolidated balance sheets and are recorded in customer receivables – net and accounts payable, respectively. (b) Reflects the netting of approximately $150 million in margin cash collateral received from counterparties. (c) Reflects the netting of approximately $56 million in margin cash collateral received from counterparties. (d) Reflects the netting of approximately $6 million in margin cash collateral paid to counterparties. (e) Reflects the netting of approximately $172 million in margin cash collateral paid to counterparties At December 31, 2022 and 2021, NEE had approximately $106 million (none at FPL) and $56 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, 2022 and 2021, NEE had approximately $268 million (none at FPL) and $673 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, 2022 are as follows: Transaction Type Fair Value at Valuation Significant Range Weighted-average (a) Assets Liabilities (millions) Forward contracts – power $ 222 $ 621 Discounted cash flow Forward price (per MWh (b) ) $(9) — $564 $51 Forward contracts – gas 349 307 Discounted cash flow Forward price (per MMBtu (c) ) $2 — $23 $4 Forward contracts – congestion 68 12 Discounted cash flow Forward price (per MWh (b) ) $(21) — $26 $1 Options – power 114 5 Option models Implied correlations 44% — 90% 56% Implied volatilities 32% — 361% 134% Options – primarily gas 726 736 Option models Implied correlations 44% — 90% 56% Implied volatilities 24% — 298% 59% Full requirements and unit contingent contracts 457 1,037 Discounted cash flow Forward price (per MWh (b) ) $13 — $424 $73 Customer migration rate (d) —% — 103% 6% Forward contracts – other 158 230 Total $ 2,094 $ 2,948 ______________________ (a) Unobservable inputs were weighted by volume. (b) Megawatt-hours (c) One million British thermal units (d) Applies only to full requirements contracts. The sensitivity of NEE's fair value measurements to increases (decreases) in the significant unobservable inputs is as follows: Significant Unobservable Input Position Impact on Forward price Purchase power/gas Increase (decrease) Sell power/gas Decrease (increase) Implied correlations Purchase option Decrease (increase) Sell option Increase (decrease) Implied volatilities Purchase option Increase (decrease) Sell option Decrease (increase) Customer migration rate Sell power (a) Decrease (increase) ———————————— (a) Assumes the contract is in a gain position. The reconciliation of changes in the fair value of derivatives that are based on significant unobservable inputs is as follows: Years Ended December 31, 2022 2021 2020 NEE FPL NEE FPL NEE FPL (millions) Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year $ 170 $ 8 $ 1,374 $ (1) $ 1,207 $ (8) Realized and unrealized gains (losses): Included in earnings (a) (2,343) — (1,488) — 547 — Included in other comprehensive income (loss) (b) — — — — 1 — Included in regulatory assets and liabilities 158 158 8 8 2 2 Purchases 542 — 243 — 191 — Sales (c) — — — — 114 — Settlements 992 (157) 259 1 (562) 6 Issuances (362) — (196) — (123) — Transfers in (d) (4) — 2 — 18 (1) Transfers out (d) (7) — (32) — (21) — Fair value of net derivatives based on significant unobservable inputs at December 31 $ (854) $ 9 $ 170 $ 8 $ 1,374 $ (1) Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date (e) $ (1,162) $ — $ (924) $ — $ 317 $ — ______________________ (a) For the years ended December 31, 2022, 2021 and 2020, realized and unrealized gains (losses) of approximately $(2,343) million, $(1,488) million and $569 million are included in the consolidated statements of income in operating revenues and the balance is included in interest expense. (b) Included in net unrealized gains (losses) on foreign currency translation in the consolidated statements of comprehensive income. (c) See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests. (d) Transfers into Level 3 were a result of decreased observability of market data. Transfers from Level 3 to Level 2 were a result of increased observability of market data. (e) For the years ended December 31, 2022, 2021 and 2020, unrealized gains (losses) of approximately $(1,162) million, $(924) million and $317 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, 2022 2021 2020 (millions) Commodity contracts (a) – operating revenues (including $2,346 unrealized losses, $2,235 unrealized losses and $163 unrealized losses, respectively) $ (3,297) $ (2,710) $ 352 Foreign currency contracts – interest expense (including $53 unrealized losses, $89 unrealized losses and $26 unrealized gains, respectively) (61) (89) 8 Interest rate contracts – interest expense (including $1,021 unrealized gains, $319 unrealized gains and $396 unrealized losses, respectively) 1,221 264 (421) Losses reclassified from AOCI: Interest rate contracts (b) (5) (7) (35) Foreign currency contracts – interest expense (3) (3) (3) Total $ (2,145) $ (2,545) $ (99) ______________________ (a) For the years ended December 31, 2022, 2021 and 2020, FPL recorded gains of approximately $211 million, $7 million and $6 million, respectively, related to commodity contracts as regulatory liabilities on its consolidated balance sheets. (b) For the year ended December 31, 2020, approximately $23 million was reclassified to gains on disposal of businesses/assets – net (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests); remaining balances were reclassified to interest expense on NEE's consolidated statements of income. Notional Volumes of Derivative Instruments – The following table represents net notional volumes associated with derivative instruments that are required to be reported at fair value in NEE's and FPL's consolidated financial statements. The table includes significant volumes of transactions that have minimal exposure to commodity price changes because they are variably priced agreements. These volumes are only an indication of the commodity exposure that is managed through the use of derivatives. They do not represent net physical asset positions or non-derivative positions and the related hedges, nor do they represent NEE's and FPL's net economic exposure, but only the net notional derivative positions that fully or partially hedge the related asset positions. NEE and FPL had derivative commodity contracts for the following net notional volumes: December 31, 2022 December 31, 2021 Commodity Type NEE FPL NEE FPL (millions) Power (104) MWh — (103) MWh — Natural gas (1,307) MMBtu 258 MMBtu (1,290) MMBtu 91 MMBtu Oil (38) barrels — (33) barrels — At December 31, 2022 and 2021, NEE had interest rate contracts with a notional amount of approximately $19.7 billion and $11.2 billion, respectively, and foreign currency contracts with a notional amount of approximately $1.0 billion and $1.0 billion, respectively. Credit-Risk-Related Contingent Features – Certain derivative instruments contain credit-risk-related contingent features including, among other things, the requirement to maintain an investment grade credit rating from specified credit rating agencies and certain financial ratios, as well as credit-related cross-default and material adverse change triggers. At December 31, 2022 and 2021, the aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately $7.4 billion ($15 million for FPL) and $4.1 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 $1,625 million (none at FPL) and $645 million (none at FPL) at December 31, 2022 and 2021, 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 $5.2 billion ($20 million at FPL) and $2.7 billion ($35 million at FPL) at December 31, 2022 and 2021, respectively. Some derivative contracts do not contain credit ratings downgrade triggers, but do contain provisions that require certain financial measures be maintained and/or have credit-related cross-default triggers. In the event these provisions were triggered, applicable NEE subsidiaries could be required to post additional collateral of up to approximately $1.1 billion ($185 million at FPL) and $1.0 billion ($145 million at FPL) at December 31, 2022 and 2021, 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, 2022 and 2021, applicable NEE subsidiaries have posted approximately $59 million (none at FPL) and $84 million (none at FPL), respectively, in cash and $1.2 billion (none at FPL) and $1.1 billion (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, 2022
Fair Value Disclosures [Abstract]
Non-Derivative Fair Value Measurements	Non-Derivative Fair Value Measurements Non-derivative fair value measurements consist of NEE’s and FPL’s cash equivalents and restricted cash equivalents, special use funds and other investments. The fair value of these financial assets is determined by using the valuation techniques and inputs as described in Note 3 – Fair Value Measurements of Derivative Instruments as well as below. Cash Equivalents and Restricted Cash Equivalents – NEE and FPL hold investments in money market funds. The fair value of these funds is estimated using a market approach based on current observable market prices. Special Use Funds and Other Investments – NEE and FPL hold primarily debt and equity securities directly, as well as indirectly through commingled funds. Substantially all directly held equity securities are valued at their quoted market prices. For directly held debt securities, multiple prices and price types are obtained from pricing vendors whenever possible, which enables cross-provider validations. A primary price source is identified based on asset type, class or issue of each security. Commingled funds, which are similar to mutual funds, are maintained by banks or investment companies and hold certain investments in accordance with a stated set of objectives. The fair value of commingled funds is primarily derived from the quoted prices in active markets of the underlying securities. Because the fund shares are offered to a limited group of investors, they are not considered to be traded in an active market. Fair Value Measurement Alternative – NEE holds investments in equity securities without readily determinable fair values, which are initially recorded at cost, of approximately $485 million and $72 million at December 31, 2022 and 2021, respectively, and are included in noncurrent other assets on NEE's consolidated balance sheets. Adjustments to carrying values are recorded as a result of observable price changes in transactions for identical or similar investments of the same issuer. 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, 2022 Level 1 Level 2 Level 3 Total (millions) Assets: Cash equivalents and restricted cash equivalents: (a) NEE – equity securities $ 961 $ — $ — $ 961 FPL – equity securities $ 36 $ — $ — $ 36 Special use funds: (b) NEE: Equity securities $ 2,062 $ 2,375 (c) $ — $ 4,437 U.S. Government and municipal bonds $ 641 $ 63 $ — $ 704 Corporate debt securities $ 6 $ 716 $ — $ 722 Asset-backed securities $ — $ 615 $ — $ 615 Other debt securities $ 1 $ 19 $ — $ 20 FPL: Equity securities $ 743 $ 2,162 (c) $ — $ 2,905 U.S. Government and municipal bonds $ 505 $ 29 $ — $ 534 Corporate debt securities $ 6 $ 547 $ — $ 553 Asset-backed securities $ — $ 473 $ — $ 473 Other debt securities $ 1 $ 11 $ — $ 12 Other investments: (d) NEE: Equity securities $ 30 $ 1 $ — $ 31 Debt securities $ 117 $ 300 $ 118 $ 535 FPL: Equity securities $ 9 $ — $ — $ 9 Debt securities $ — $ 114 $ — $ 114 ______________________ (a) Includes restricted cash equivalents of approximately $69 million ($33 million for FPL) in current other assets (b) Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below. (c) Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL. (d) Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets. December 31, 2021 Level 1 Level 2 Level 3 Total (millions) Assets: Cash equivalents and restricted cash equivalents: (a) NEE – equity securities $ 176 $ — $ — $ 176 FPL – equity securities $ 58 $ — $ — $ 58 Special use funds: (b) NEE: Equity securities $ 2,538 $ 2,973 (c) $ — $ 5,511 U.S. Government and municipal bonds $ 770 $ 75 $ — $ 845 Corporate debt securities $ 7 $ 955 $ — $ 962 Asset-backed securities $ — $ 663 $ — $ 663 Other debt securities $ 2 $ 33 $ — $ 35 FPL: Equity securities $ 862 $ 2,690 (c) $ — $ 3,552 U.S. Government and municipal bonds $ 624 $ 44 $ — $ 668 Corporate debt securities $ 6 $ 720 $ — $ 726 Asset-backed securities $ — $ 515 $ — $ 515 Other debt securities $ 2 $ 23 $ — $ 25 Other investments: (d) NEE: Equity securities $ 70 $ 2 $ — $ 72 Debt securities $ 111 $ 162 $ 12 $ 285 FPL – equity securities $ 13 $ — $ — $ 13 ______________________ (a) Includes restricted cash equivalents of approximately $56 million ($53 million for FPL) in current other assets (b) Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below. (c) Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL. (d) Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets. Contingent Consideration – NEER had approximately $203 million and $261 million of contingent consideration liabilities at December 31, 2022 and 2021, respectively, which are included in noncurrent other liabilities on NEE's consolidated balance sheets. The liabilities relate to contingent consideration for the completion of capital expenditures for future development projects in connection with the acquisition of GridLiance Holdco, LP and GridLiance GP, LLC (GridLiance) (see Note 6 – GridLiance). NEECH guarantees the contingent consideration obligations under the GridLiance acquisition agreements. Significant inputs and assumptions used in the fair value measurement, some of which are Level 3 and require judgement, include the projected timing and amount of future cash flows, estimated probability of completing future development projects as well as discount rates. Fair Value of Financial Instruments Recorded at Other than Fair Value – The carrying amounts of commercial paper and other short-term debt approximate their fair values. The carrying amounts and estimated fair values of other financial instruments recorded at other than fair value are as follows: December 31, 2022 December 31, 2021 Carrying Estimated Carrying Estimated (millions) NEE: Special use funds (a) $ 998 $ 999 $ 906 $ 907 Other receivables, net of allowances (b) $ 221 $ 221 $ 26 $ 26 Long-term debt, including current portion $ 61,889 $ 57,892 (c) $ 52,745 $ 57,290 (c) FPL: Special use funds (a) $ 744 $ 744 $ 672 $ 672 Long-term debt, including current portion $ 21,002 $ 19,364 (c) $ 18,510 $ 21,379 (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 (primarily Level 3). (c) At December 31, 2022 and 2021, substantially all is Level 2 for NEE and FPL. Special Use Funds and Other Investments Carried at Fair Value – 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 $7,495 million ($5,220 million for FPL) and $8,846 million ($6,082 million for FPL) at December 31, 2022 and 2021, respectively, and FPL's storm fund assets of $1 million and $76 million at December 31, 2022 and 2021, respectively. The investments held in the special use funds and other investments 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 $2,858 million ($1,873 million for FPL) and $2,438 million ($1,877 million for FPL) at December 31, 2022 and 2021, respectively. Debt securities included in the nuclear decommissioning funds have a weighted-average maturity at December 31, 2022 of approximately nine years at both NEE and FPL. Other investments primarily consist of debt securities with a weighted-average maturity at December 31, 2022 of approximately seven years. The cost of securities sold is determined using the specific identification method. 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 primarily 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, 2022, 2021 and 2020 are as follows: NEE FPL Years Ended December 31, Years Ended December 31, 2022 2021 2020 2022 2021 2020 (millions) Unrealized gains (losses) $ (1,028) $ 981 $ 627 $ (677) $ 652 $ 444 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, 2022 2021 2020 2022 2021 2020 (millions) Realized gains $ 30 $ 78 $ 110 $ 24 $ 59 $ 83 Realized losses $ 141 $ 73 $ 70 $ 111 $ 57 $ 56 Proceeds from sale or maturity of securities $ 2,207 $ 1,831 $ 2,541 $ 1,371 $ 1,330 $ 2,162 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, 2022 2021 2022 2021 (millions) Unrealized gains $ 4 $ 76 $ 3 $ 63 Unrealized losses (a) $ 285 $ 19 $ 193 $ 15 Fair value $ 2,315 $ 1,100 $ 1,466 $ 857 ______________________ (a) Unrealized losses on available for sale debt securities in an unrealized loss position for greater than twelve months at December 31, 2022 and 2021 were not material to NEE or FPL. Regulations issued by the FERC and the NRC provide general risk management guidelines to protect nuclear decommissioning funds and to allow such funds to earn a reasonable return. The FERC regulations prohibit, among other investments, investments in any securities of NEE or its subsidiaries, affiliates or associates, excluding investments tied to market indices or mutual funds. Similar restrictions applicable to the decommissioning funds for NEER's nuclear plants are included in the NRC operating licenses for those facilities or in NRC regulations applicable to NRC licensees not in cost-of-service environments. With respect to the decommissioning fund for Seabrook, decommissioning fund contributions and withdrawals are also regulated by the NDFC pursuant to New Hampshire law. The nuclear decommissioning reserve funds are managed by investment managers who must comply with the guidelines of NEE and FPL and the rules of the applicable regulatory authorities. The funds' assets are invested giving consideration to taxes, liquidity, risk, diversification and other prudent investment objectives. Nonrecurring Fair Value Measurements – NEE tests its equity method investments for impairment whenever events or changes in circumstances indicate that the investment may be impaired. During the preparation of NEE's December 31, 2020 financial statements, it was determined that NextEra Energy Resources' investment in Mountain Valley Pipeline, LLC (Mountain Valley Pipeline) accounted for under the equity method of accounting was other-than-temporarily impaired. The impairment is the result of continued legal and regulatory challenges that have resulted in substantial delays in achieving commercial operation and increased costs to complete construction. More specifically at the end of 2020 and into early 2021, developments in the legal, regulatory and political environment caused NextEra Energy Resources to consider the investment impaired and the impairment to be other than temporary. The challenges included legal challenges to the various permits needed to complete construction and the regulatory approvals received, regulatory challenges related to alternative construction plans and the extended construction period, and the political and environmental challenges with the construction of an interstate pipeline. Accordingly, NextEra Energy Resources performed a fair value analysis based on the market approach to determine the amount of the impairment. The challenges to complete construction and the resulting economic outlook for the pipeline were considered in determining the magnitude of the other-than-temporary impairment. Based on the fair value analysis, the equity method investment with a carrying amount of approximately $1.9 billion was written down to its estimated fair value of approximately $400 million as of December 31, 2020, resulting in an impairment charge of $1.5 billion (or $1.2 billion after tax), which is recorded in equity in earnings (losses) of equity method investees The fair value estimate was based on a probability-weighted earnings before interest, taxes, depreciation and amortization (EBITDA) multiple valuation technique using a market participant view of the potential different outcomes for the investment. As part of the valuation, NextEra Energy Resources used observable inputs where available, including the EBITDA multiples of recent pipeline transactions. Significant unobservable inputs (Level 3), including the probabilities assigned to the different potential outcomes, the forecasts of operating revenues and costs, and the projected capital expenditures to complete the project, were also used in the estimation of fair value. An increase in the revenue forecasts, a decrease in the projected operating or capital expenditures or an increase in the probability assigned to the full pipeline being completed would result in an increased fair market value. Changes in the opposite direction of those unobservable inputs would result in a decreased fair market value. On February 2, 2022, the U.S. Court of Appeals for the Fourth Circuit (the 4th Circuit) vacated and remanded Mountain Valley Pipeline’s Biological Opinion issued by the U.S. Fish and Wildlife Service. While NextEra Energy Resources continues to evaluate options and next steps with its joint venture partners, this event along with the 4th Circuit vacatur and remand of the U.S. Forest Service right-of-way grant on January 25, 2022 caused NextEra Energy Resources to re-evaluate its investment in Mountain Valley Pipeline for further other-than-temporary impairment, which evaluation coincided with the preparation of NEE's December 31, 2021 financial statements. As a result of this evaluation, it was determined that the continued legal and regulatory challenges have resulted in a very low probability of pipeline completion. Accordingly, NextEra Energy Resources updated its fair value estimate using the same probability-weighted EBITDA multiple valuation technique using a market participant view of the potential different outcomes for the investment as discussed above. Based on this fair value analysis, NextEra Energy Resources recorded an impairment charge in the first quarter of 2022 of approximately $0.8 billion ($0.6 billion after tax), which is reflected in equity in earnings (losses) of equity method investees in NEE's consolidated statements of income for the year

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes On August 16, 2022, the IRA was signed into law which includes: (i) extensions for wind and solar tax credits on facilities that start construction before the later of 2034 or the end of the calendar year following the year in which greenhouse gas emissions from U.S. electric generation are reduced by 75% from 2022 levels; (ii) a new solar PTC and standalone battery ITC; (iii) the ability to transfer renewable energy tax credits to an unrelated transferee; and (iv) a 15% corporate profits minimum tax based on pre-tax income for years after 2022. This legislation does not require NEE or FPL to revalue their deferred income taxes given that there was no change to the corporate tax rate. Pursuant to FPL’s 2021 rate agreement, FPL refunded customers approximately $36 million in January 2023 and will prospectively adjust base rates after a review by the FPSC for PTCs related to new solar generation facilities recovered in base rates during the term of the 2021 rate agreement (see Note 1 – Rate Regulation). The components of income taxes are as follows: NEE FPL Years Ended December 31, Years Ended December 31, 2022 2021 2020 2022 2021 2020 (millions) Federal: Current $ 11 $ (26) $ 105 $ 3 $ 85 $ 16 Deferred 497 311 (148) 684 545 474 Total federal 508 285 (43) 687 630 490 State: Current 41 (62) 18 2 1 32 Deferred 37 125 69 258 207 156 Total state 78 63 87 260 208 188 Total income taxes $ 586 $ 348 $ 44 $ 947 $ 838 $ 678 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, 2022 2021 2020 2022 2021 2020 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 1.6 1.6 2.8 4.4 4.1 4.2 Taxes attributable to noncontrolling interests 4.9 5.0 4.8 — — — PTCs and ITCs (6.8) (11.3) (12.7) (1.1) (0.7) (0.6) Amortization of deferred regulatory credit (4.8) (4.4) (7.2) (4.0) (3.5) (4.9) Foreign operations (a) 0.1 0.2 (2.4) — — — Other – net (0.7) (1.1) (4.5) 0.1 (0.2) (0.7) Effective income tax rate 15.3 % 11.0 % 1.8 % 20.4 % 20.7 % 19.0 % _________________________ (a) The 2020 gain on sale of the Spain solar projects was not taxable for federal and state income tax purposes (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests). The income tax effects of temporary differences giving rise to consolidated deferred income tax liabilities and assets are as follows: NEE FPL December 31, December 31, 2022 2021 2022 2021 (millions) Deferred tax liabilities: Property-related $ 10,144 $ 10,018 $ 8,177 $ 7,831 Pension 552 564 439 425 Investments in partnerships and joint ventures 3,144 2,783 3 3 Other 2,666 2,092 1,914 1,232 Total deferred tax liabilities 16,506 15,457 10,533 9,491 Deferred tax assets and valuation allowance: Decommissioning reserves 306 296 306 296 Net operating loss carryforwards 346 330 19 2 Tax credit carryforwards 4,905 4,646 123 182 ARO and accrued asset removal costs 199 199 107 126 Regulatory liabilities 1,332 1,421 1,308 1,397 Other 822 733 295 351 Valuation allowance (a) (257) (282) — — Net deferred tax assets 7,653 7,343 2,158 2,354 Net deferred income taxes $ 8,853 $ 8,114 $ 8,375 $ 7,137 ______________________ (a) Reflects valuation allowances related to deferred state tax credits and state operating loss carryforwards. Deferred tax assets and liabilities are included on the consolidated balance sheets as follows: NEE FPL December 31, December 31, 2022 2021 2022 2021 (millions) Noncurrent other assets $ 219 $ 196 $ 1 $ — Deferred income taxes – noncurrent liabilities (9,072) (8,310) (8,376) (7,137) Net deferred income taxes $ (8,853) $ (8,114) $ (8,375) $ (7,137) The components of NEE's deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2022 are as follows: Amount Expiration (millions) Net operating loss carryforwards: Federal $ 11 (a) 2033 – 2037 State 315 2022 – 2042 Foreign 20 (b) 2026 – 2042 Net operating loss carryforwards $ 346 Tax credit carryforwards: Federal $ 4,555 2028 – 2042 State 345 (c) 2023 – 2039 Foreign 5 2034 – 2042 Tax credit carryforwards $ 4,905 ______________________ (a) Includes $9 million of net operating loss carryforwards with an indefinite expiration period. (b) Includes $1 million of net operating loss carryforwards with an indefinite expiration period. (c) Includes $191 million of ITC carryforwards with an indefinite expiration period.

Acquisitions Acquisitions

Acquisitions Acquisitions	12 Months Ended
	Dec. 31, 2022
Business Combinations [Abstract]
Acquisitions	Acquisitions Merger of FPL and Gulf Power Company – On January 1, 2021, FPL and Gulf Power Company merged, with FPL as the surviving entity. However, during 2021, FPL continued to be regulated as two separate ratemaking entities in the former service areas of FPL and Gulf Power Company . Effective January 1, 2022, FPL became regulated as one electric ratemaking entity with new unified rates and tariffs, and also became one reportable segment of NEE. See Note 1 – Rate Regulation – Base Rates Effective January 2022 through December 2025 and 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, $729 million of deferred income taxes and $566 million of regulatory liabilities. Additionally, goodwill of approximately $2.7 billion and purchase accounting adjustments associated with the 2019 Gulf Power Company acquisition by NEE were transferred to FPL from Corporate and Other and, for impairment testing, the goodwill is included in the FPL reporting unit. The assets acquired and liabilities assumed by FPL were at carrying amounts as the merger was between entities under common control. GridLiance – On March 31, 2021, a wholly owned subsidiary of NEET acquired GridLiance, which owns and operates three FERC-regulated transmission utilities with approximately 700 miles of high-voltage transmission lines across six states, five in the Midwest and Nevada. The purchase price included approximately $502 million in cash consideration, and the assumption of approximately $175 million of debt, excluding post-closing adjustments. Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed based on their fair value. The approval by the FERC of GridLiance's rates, which is intended to allow GridLiance to collect total revenues equal to GridLiance's costs for the development, financing, construction, operation and maintenance of GridLiance, including a reasonable rate of return on invested capital, is considered a fundamental input in measuring the fair value of GridLiance's assets and liabilities and, as such, NEE concluded that the carrying values of all assets and liabilities recoverable through rates are representative of their fair values. As a result, NEE acquired assets of approximately $384 million, primarily relating to property, plant and equipment, and assumed liabilities of approximately $210 million, primarily relating to long-term debt. The acquisition agreements are subject to earn-out provisions for additional payments, valued at approximately $264 million at March 31, 2021, to be made upon the completion of capital expenditures for future development projects (see Note 4 – Contingent Consideration). The excess of the purchase price over the fair value of assets acquired and liabilities assumed resulted in approximately $592 million of goodwill which has been recognized on NEE's consolidated balance sheets, of which approximately $586 million is expected to be deductible for tax purposes. Goodwill associated with the GridLiance acquisition is reflected within NEER and, for impairment testing, is included in the rate-regulated transmission reporting unit. The goodwill arising from the transaction represents expected benefits from continued expansion of NEE's regulated businesses. RNG Acquisition – On October 27, 2022, a wholly owned subsidiary of NextEra Energy Resources entered into several agreements to acquire 100% of a portfolio of renewable energy projects from the owners of Energy Power Partners Fund I, L.P. and North American Sustainable Energy Fund, L.P., as well as the related service provider, for approximately $1.1 billion, subject to closing adjustments, plus the assumption of approximately $37 million of existing project finance debt estimated at the time of closing. The portfolio primarily consists of 31 biogas projects, one of which is an operating renewable natural gas facility and the others of which are primarily operating landfill gas-to-electric facilities. The acquisition is expected to close in early 2023, subject to receipt of required regulatory approvals including approvals from the FERC.

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2022
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment consists of the following at December 31: NEE FPL 2022 2021 2022 2021 (millions) Electric plant in service and other property $ 124,963 $ 112,500 $ 74,353 $ 67,771 Nuclear fuel 1,684 1,606 1,190 1,170 Construction work in progress 15,675 14,141 7,026 6,326 Property, plant and equipment, gross 142,322 128,247 82,569 75,267 Accumulated depreciation and amortization (31,263) (28,899) (17,876) (17,040) Property, plant and equipment – net $ 111,059 $ 99,348 $ 64,693 $ 58,227 FPL – At December 31, 2022, 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 44%, 14%, 35% and 7%, respectively; the respective amounts at December 31, 2021 were 46%, 13%, 35% and 6%. Substantially all of FPL's properties are subject to the lien of FPL's mortgage, which secures most debt securities issued by FPL. The weighted annual composite depreciation and amortization rate for FPL's electric plant in service, including capitalized software, but excluding the effects of decommissioning, dismantlement and the depreciation adjustments discussed in the following sentences, was approximately 3.6%, 3.8% and 3.8% for 2022, 2021 and 2020, respectively. In 2022, FPL recorded a one-time reserve amortization adjustment of approximately $114 million, as required under the 2021 rate agreement, 50% of which was used to reduce the capital recovery regulatory asset balance and the other 50% to increase the storm reserve regulatory liability (see Note 1 – Storm Funds, Storm Reserves and Storm Cost Recovery). In accordance with the 2016 rate agreement (see Note 1 – Rate Regulation – Base Rates Effective January 2017 through December 2021), FPL recorded reserve amortization (reversal) of approximately $429 million and $(1) million in 2021 and 2020, respectively. During 2022, 2021 and 2020, FPL recorded AFUDC of approximately $136 million, $176 million and $117 million , respectively, including the equity component of AFUDC of approximately $105 million, $132 million and $87 million, respectively. NEER – At December 31, 2022, wind, solar and nuclear plants represented approximately 51%, 14% and 7%, respectively, of NEER's depreciable electric plant in service and other property; the respective amounts at December 31, 2021 were 53%, 14% and 8%. The estimated useful lives of NEER's plants range primarily from 30 to 35 years for wind plants, 30 to 35 years for solar plants and 23 to 47 years for nuclear plants. NEER's oil and gas production assets represented approximately 15% and 14% of NEER's depreciable electric plant in service and other property at December 31, 2022 and 2021, 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 $14.4 billion at December 31, 2022. Interest capitalized on construction projects amounted to approximately $172 million, $139 million and $168 million during 2022, 2021 and 2020, 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, 2022 Ownership Gross Investment (a) Accumulated Depreciation (a) Construction (millions) FPL: St. Lucie Unit No. 2 85 % $ 2,276 $ 1,062 $ 163 Daniel Units Nos. 1 and 2 (b) 50 % $ 753 $ 285 $ 22 Scherer Unit No. 3 (c) 25 % $ 405 $ 169 $ 1 NEER: Seabrook 88.23 % $ 1,355 $ 494 $ 74 Wyman Station Unit No. 4 91.19 % $ 31 $ 12 $ — Stanton 65 % $ 139 $ 25 $ — Transmission substation assets located in Seabrook, New Hampshire 88.23 % $ 140 $ 4 $ 4 ______________________ (a) Excludes nuclear fuel. (b) FPL intends to retire its share of these units in 2024. Net book value is reflected in other property on NEE's and FPL's consolidated balance sheets.

Equity Method Investments

Equity Method Investments	12 Months Ended
	Dec. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Equity Method InvestmentsAt December 31, 2022 and 2021, NEE's equity method investments totaled approximately $6,582 million and $6,159 million, respectively. The principal entities included in investment in equity method investees on NEE's consolidated balance sheets are NEP OpCo and Sabal Trail Transmission, LLC (Sabal Trail) (see Note 15 – Contracts), and in 2021 also included Mountain Valley Pipeline (see Note 4 – Nonrecurring Fair Value Measurements and Note 15 - Contracts) and Silver State South Solar, LLC. As of December 31, 2022, NEE's interest in the principal entities range from approximately 43% to 54%, and these entities primarily own natural gas pipelines or electric generation facilities. Summarized combined information for these principal entities is as follows: 2022 2021 (millions) Operating revenue $ 1,705 $ 1,469 Operating income $ 1,423 $ 559 Net income $ 1,380 $ 739 Total assets $ 26,058 $ 29,537 Total liabilities $ 9,779 $ 9,501 Partners'/members' equity (a) $ 16,279 $ 20,036 NEE's share of underlying equity in the principal entities $ 2,379 $ 4,352 Difference between investment carrying amount and underlying equity in net assets (b) 2,589 1,133 NEE's investment carrying amount for the principal entities $ 4,968 $ 5,485 ______________________ (a) Reflects NEE's interest, as well as third-party interests, in NEP OpCo. (b) Approximately $2.5 billion in 2022 and $2.6 billion in 2021 is associated with NEP OpCo, of which approximately 75% relates to goodwill and is not being amortized and the remaining balance is being amortized primarily over a period of 13 to 25 years. The difference for 2021 is net of an approximately $1.5 billion impairment charge in 2020 related to NextEra Energy Resources' investment in Mountain Valley Pipeline. See Note 4 – Nonrecurring Fair Value Measurements for a discussion of impairment charges in 2020 and 2022. NextEra Energy Resources provides operational, management and administrative services as well as transportation and fuel management services to NEP and its subsidiaries under various agreements (service agreements). NextEra Energy Resources is also party to a cash sweep and credit support (CSCS) agreement with a subsidiary of NEP. At December 31, 2022 and 2021, the cash sweep amounts (due to NEP and its subsidiaries) held in accounts belonging to NextEra Energy Resources or its subsidiaries were approximately $298 million and $57 million, respectively, and are included in accounts payable. Fee income related to the CSCS agreement and the service agreements totaled approximately $174 million, $148 million and $120 million for the years ended December 31, 2022, 2021 and 2020, respectively, and is included in operating revenues in NEE's consolidated statements of income. Amounts due from NEP of approximately $94 million and $113 million are included in other receivables and $101 million and $40 million are included in noncurrent other assets at December 31, 2022 and 2021, respectively. See also Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests for amounts due to NEP for reimbursement of construction-related costs. NEECH or NextEra Energy Resources guaranteed or provided indemnifications, letters of credit or surety bonds totaling approximately $4,600 million at December 31, 2022 primarily related to obligations on behalf of NEP's subsidiaries with maturity dates ranging from 2023 to 2059, including certain project performance obligations, obligations under financing and interconnection agreements and obligations, primarily incurred and future construction payables, associated with the December 2022 sale of projects to NEP (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests). Payment guarantees and related contracts with respect to unconsolidated entities for which NEE or one of its subsidiaries are the guarantor are recorded on NEE’s consolidated balance sheets at fair value. At December 31, 2022, approximately $56 million related to the fair value of the credit support provided under the CSCS agreement is recorded as noncurrent other liabilities on NEE's consolidated balance sheet. During 2022, 2021 and 2020, certain services, primarily engineering, construction and maintenance services, were provided to subsidiaries of NEE by related parties that NEE accounts for under the equity method of accounting. Charges for these services amounted to approximately $579 million, $691 million and $721 million for the years ended December 31, 2022, 2021 and 2020, respectively.

Variable Interest Entities (VIE

Variable Interest Entities (VIEs)	12 Months Ended
	Dec. 31, 2022
Variable Interest Entities [Abstract]
Variable Interest Entities (VIEs)	Variable Interest Entities (VIEs) NEER – At December 31, 2022, NEE consolidates a number of VIEs within the NEER segment. Subsidiaries within the NEER segment are considered the primary beneficiary of these VIEs since they control the most significant activities of these VIEs, including operations and maintenance, and they have the obligation to absorb expected losses of these VIEs. Nine indirect subsidiaries of NextEra Energy Resources have an ownership interest ranging from approximately 50% to 67% in entities which own and operate solar facilities with the capability of producing a total of approximately 772 MW, and own a solar generation and battery storage facility that is expected to have total generating/storage capacity of approximately 125 MW and 65 MW, respectively, upon completion of construction, which is expected in 2023. Each of the subsidiaries is considered a VIE since the non-managing members have no substantive rights over the managing members, and is consolidated by NextEra Energy Resources. These entities sell their electric output to third parties under power sales contracts with expiration dates ranging from 2035 through 2052. These entities have third-party debt which is secured by liens against the assets of the entities. The debt holders have no recourse to the general credit of NextEra Energy Resources for the repayment of debt. The assets and liabilities of these VIEs were approximately $2,084 million and $1,174 million, respectively, at December 31, 2022. There were eight of these consolidated VIEs at December 31, 2021 and the assets and liabilities of those VIEs at such date totaled approximately $1,851 million and $1,258 million, respectively. At December 31, 2022 and 2021, the assets and liabilities of these VIEs consisted primarily of property, plant and equipment and long-term debt. At December 31, 2022, subsidiaries of NEE had guarantees related to certain obligations of one of these consolidated VIEs. NEE consolidates a NEET VIE which owns and operates an approximately 280-mile electric transmission line that went into service during the first quarter of 2022. A NEET subsidiary is the primary beneficiary and controls the most significant activities of the VIE. NEET is entitled to receive 50% of the profits and losses of the entity. The assets and liabilities of the VIE totaled approximately $744 million and $18 million, respectively, at December 31, 2022, and $614 million and $64 million, respectively, at December 31, 2021. At December 31, 2022 and 2021, the assets of this VIE consisted primarily of property, plant and equipment. NextEra Energy Resources consolidates a VIE which has a 10% direct ownership interest in wind and solar generation facilities which have the capability of producing approximately 400 MW and 599 MW, respectively. These entities sell their electric output under power sales contracts to third parties with expiration dates ranging from 2025 through 2040. These entities are also considered a VIE because the holders of differential membership interests in these entities do not have substantive rights over the significant activities of these entities. The assets and liabilities of the VIE were approximately $1,488 million and $86 million, respectively, at December 31, 2022, and $1,518 million and $79 million, respectively, at December 31, 2021. At December 31, 2022 and 2021, the assets of this VIE consisted primarily of property, plant and equipment. NextEra Energy Resources consolidates 31 VIEs that primarily relate to certain subsidiaries which have sold differential membership interests in entities which own and operate wind generation, solar generation and battery storage facilities with generating/storage capacity of approximately 11,712 MW, 600 MW and 324 MW, respectively, and own wind generation, solar generation and battery storage facilities that, upon completion of construction, which is anticipated in 2023, are expected to have generating/storage capacity of approximately 301 MW, 1,161 MW and 390 MW, respectively. These entities sell, or will sell, their electric output either under power sales contracts to third parties with expiration dates ranging from 2024 through 2053 or in the spot market. These entities are considered VIEs because the holders of differential membership interests do not have substantive rights over the significant activities of these entities. NextEra Energy Resources has financing obligations with respect to these entities, including third-party debt which is secured by liens against the generation facilities and the other assets of these entities or by pledges of NextEra Energy Resources' ownership interest in these entities. The debt holders have no recourse to the general credit of NEER for the repayment of debt. The assets and liabilities of these VIEs totaled approximately $19,690 million and $2,318 million, respectively, at December 31, 2022. There were 33 of these consolidated VIEs at December 31, 2021 and the assets and liabilities of those VIEs at such date totaled approximately $17,419 million and $1,480 million, respectively. At December 31, 2022 and 2021, the assets and liabilities of these VIEs consisted primarily of property, plant and equipment and accounts payable. At December 31, 2022, subsidiaries of NEE had guarantees related to certain obligations of three of these consolidated VIEs. Other – At December 31, 2022 and 2021, several NEE subsidiaries had investments totaling approximately $4,016 million ($3,331 million at FPL) and $4,559 million ($3,799 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 asset-backed securities. NEE subsidiaries, including FPL, are not the primary beneficiaries and therefore do not consolidate any of these entities because they do not control any of the ongoing activities of these entities, were not involved in the initial design of these entities and do not have a controlling financial interest in these entities. Certain subsidiaries of NEE have noncontrolling interests in entities accounted for under the equity method, including NEE's noncontrolling interest in NEP OpCo (see Note 8). These entities are limited partnerships or similar entity structures in which the limited partners or non-managing members do not have substantive rights over the significant activities of these entities, and therefore are considered VIEs. NEE is not the primary beneficiary because it does not have a controlling financial interest in these entities, and therefore does not consolidate any of these entities. NEE’s investment in these entities totaled approximately $5,214 million and $4,214 million at December 31, 2022 and 2021, respectively. At December 31, 2022, subsidiaries of NEE had guarantees related to certain obligations of one of these entities, as well as commitments to invest an additional approximately $180 million in several of these entities. See further discussion of such guarantees and commitments in Note 15 – Commitments and – Contracts, respectively.

Leases

Leases	12 Months Ended
	Dec. 31, 2022
Leases [Abstract]
Leases	LeasesNEE has operating and finance leases primarily related to land use agreements that convey exclusive use of the land during the arrangement for certain of its renewable energy projects and substations, buildings, equipment and, in 2021, purchased power agreements. Operating and finance leases primarily have fixed payments with expected expiration dates ranging from 2023 to 2083, with the exception of operating leases related to three land use agreements with an expiration date of 2106, some of which include options to extend the leases up to 20 years and some have options to terminate at NEE's discretion. At December 31, 2022, NEE’s ROU assets lease liabilities ROU assets lease liabilities NEE has operating and sales-type leases primarily related to a natural gas and oil electric generation facility and certain battery storage facilities that sell their electric output under power sales agreements to third parties which provide the customers the ability to dispatch the facilities. At December 31, 2022 and 2021, NEE recorded a net investment in sales-type leases of approximately $53 million and $42 million, respectively. At December 31, 2022, the power sales agreements have expiration dates from 2024 to 2043 and NEE expects to receive approximately $1.1 billion of lease payments over the remaining terms of the power sales agreements with no one year being material. Operating and sales-type lease-related amounts were not material to NEE's consolidated statements of income for the periods presented.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2022
Asset Retirement Obligations [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations NEE's AROs relate primarily to decommissioning obligations of FPL's and NEER's nuclear units and to obligations for the dismantlement of certain of NEER's wind and solar facilities. For NEE's rate-regulated operations, including FPL, the accounting provisions result in timing differences in the recognition of legal asset retirement costs for financial reporting purposes and the method the regulator allows for recovery in rates. See Note 1 – Rate Regulation and – Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs. A rollforward of NEE's and FPL's AROs is as follows: NEE FPL (millions) Balances, December 31, 2020 $ 3,166 $ 1,936 Liabilities incurred 79 7 Accretion expense 141 78 Liabilities settled (88) (a) (15) Revision in estimated cash flows – net (119) (b) 101 (c) Balances, December 31, 2021 3,179 (d) 2,107 (d) Liabilities incurred 82 — Accretion expense 145 81 Liabilities settled (80) (a) (22) Revision in estimated cash flows – net 2 10 Balances, December 31, 2022 $ 3,328 (d) $ 2,176 (d) ______________________ (a) Includes approximately $27 million and $35 million related to project sales to NEP as well as other sales of businesses and assets during the years ending December 31, 2022 and 2021, respectively. See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests. (b) The increase at FPL discussed in (c) was offset primarily by the effect of revised cost estimates and useful lives of NEER's solar facilities. (c) Primarily reflects the effect of pending license extension requests of St. Lucie Units Nos. 1 and 2 for an additional 20 years. (d) Includes the current portion of AROs as of December 31, 2022 and 2021 of approximately $83 million ($68 million for FPL) and $97 million ($58 million for FPL), respectively, which are included in other current liabilities on NEE's and FPL's consolidated balance sheets. 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). 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, 2022 $ 7,495 $ 5,220 Balances, December 31, 2021 $ 8,846 $ 6,082 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

Employee Retirement Benefits

Employee Retirement Benefits	12 Months Ended
	Dec. 31, 2022
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 $237 million ($115 million for FPL) and $300 million ($139 million for FPL) at December 31, 2022 and 2021, 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: 2022 2021 (millions) Change in pension plan assets: Fair value of plan assets at January 1 $ 5,688 $ 5,314 Actual return on plan assets (820) 627 Benefit payments (325) (253) Fair value of plan assets at December 31 $ 4,543 $ 5,688 Change in pension benefit obligation: Obligation at January 1 $ 3,445 $ 3,607 Service cost 86 90 Interest cost 77 64 Special termination benefit (a) 52 — Plan amendments 3 — Actuarial gains – net (627) (63) Benefit payments (325) (253) Obligation at December 31 (b) $ 2,711 $ 3,445 Funded status: Prepaid pension benefit costs at NEE at December 31 $ 1,832 $ 2,243 Prepaid pension benefit costs at FPL at December 31 (c) $ 1,732 $ 1,657 _________________________ (a) Reflects enhanced early retirement benefit. (b) NEE's accumulated pension benefit obligation, which includes no assumption about future salary levels, at December 31, 2022 and 2021 was approximately $2,650 million and $3,352 million, respectively. (c) Reflects FPL's allocated benefits under NEE's pension plan. NEE's unrecognized amounts included in accumulated other comprehensive income (loss) yet to be recognized as components of prepaid pension benefit costs are as follows: 2022 2021 (millions) Unrecognized prior service benefit (net of $0 tax expense and $1 tax expense, respectively) $ 1 $ 2 Unrecognized gains (losses) (net of $33 tax benefit and $7 tax expense, respectively) (91) 41 Total $ (90) $ 43 NEE's unrecognized amounts included in regulatory assets (liabilities) yet to be recognized as components of net prepaid pension benefit costs are as follows: 2022 2021 (millions) Unrecognized prior service cost (benefit) $ 2 $ (1) Unrecognized losses (gains) 277 (80) Total $ 279 $ (81) 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. 2022 2021 Discount rate 5.05 % 2.87 % Salary increase 4.90 % 4.90 % Weighted-average interest crediting rate 3.82 % 3.79 % 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 43% equity investments, 32% fixed income investments, 20% alternative investments and 5% 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, 2022 (a) Quoted Prices Significant Significant Total (millions) Equity securities (b) $ 1,246 $ 5 $ 1 $ 1,252 Equity commingled vehicles (c) — 731 — 731 U.S. Government and municipal bonds 85 5 — 90 Corporate debt securities (d) — 272 — 272 Asset-backed securities (e) — 413 — 413 Debt security commingled vehicles — 130 — 130 Convertible securities (f) 50 367 — 417 Total investments in the fair value hierarchy $ 1,381 $ 1,923 $ 1 3,305 Total investments measured at net asset value (g) 1,238 Total fair value of plan assets $ 4,543 _____________________ (a) See Notes 3 and 4 for discussion of fair value measurement techniques and inputs. (b) Includes foreign investments of $526 million. (c) Includes foreign investments of $191 million. (d) Includes foreign investments of $83 million. (e) Includes foreign investments of $129 million. (f) Includes foreign investments of $30 million. (g) Includes foreign investments of $242 million. December 31, 2021 (a) Quoted Prices Significant Significant Total (millions) Equity securities (b) $ 1,977 $ 29 $ 2 $ 2,008 Equity commingled vehicles (c) — 889 — 889 U.S. Government and municipal bonds 131 6 — 137 Corporate debt securities (d) — 351 — 351 Asset-backed securities — 386 — 386 Debt security commingled vehicles (e) — 219 — 219 Convertible securities (f) 91 489 — 580 Total investments in the fair value hierarchy $ 2,199 $ 2,369 $ 2 4,570 Total investments measured at net asset value (g) 1,118 Total fair value of plan assets $ 5,688 ______________________ (a) See Notes 3 and 4 for discussion of fair value measurement techniques and inputs. (b) Includes foreign investments of $927 million. (c) Includes foreign investments of $169 million. (d) Includes foreign investments of $109 million. (e) Includes foreign investments of $5 million. (f) Includes foreign investments of $41 million. (g) Includes foreign investments of $220 million. 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): 2023 $ 198 2024 $ 199 2025 $ 201 2026 $ 204 2027 $ 203 2028 – 2032 $ 1,008 Net Periodic (Income) Cost – The components of net periodic (income) cost for the plans are as follows: Pension Benefits Postretirement Benefits 2022 2021 2020 2022 2021 2020 (millions) Service cost $ 86 $ 90 $ 85 $ 1 $ 2 $ 1 Interest cost 77 64 92 5 4 8 Expected return on plan assets (363) (339) (321) — — — Amortization of actuarial loss — 24 18 3 5 3 Amortization of prior service benefit (1) (1) (1) (4) (15) (16) Special termination benefit 52 — 16 — — — Benefit plan settlement 27 — — — — — Net periodic (income) cost at NEE $ (122) $ (162) $ (111) $ 5 $ (4) $ (4) Net periodic (income) cost allocated to FPL $ (76) $ (108) $ (84) $ 4 $ (4) $ (4) Other Comprehensive Income – The components of net periodic income (cost) recognized in OCI for the pension plan are as follows: 2022 2021 2020 (millions) Prior service cost (net of $0 tax benefit) $ (1) $ — $ — Net gains (losses) (net of $43 tax benefit, $29 tax expense and $13 tax expense, respectively) (139) 95 42 Amortization of unrecognized losses (net of $2 tax expense, $2 tax expense and $1 tax expense, respectively) 7 6 5 Total $ (133) $ 101 $ 47 Regulatory Assets (Liabilities) – The components of net periodic income recognized during the year in regulatory assets (liabilities) for the pension plan are as follows: 2022 2021 (millions) Prior service cost (benefit) $ 2 $ (1) Unrecognized losses (gains) 375 (226) Amortization of prior service benefit 1 — Amortization of unrecognized losses (18) (16) Total $ 360 $ (243) The assumptions used to determine net periodic pension income for the pension plan are as follows: 2022 2021 2020 Discount rate 2.87 % 2.53 % 3.22 % Salary increase 4.90 % 4.40 % 4.40 % Expected long-term rate of return, net of investment management fees 7.35 % 7.35 % 7.35 % Weighted-average interest crediting rate 3.79 % 3.82 % 3.83 %

Debt

Debt	12 Months Ended
	Dec. 31, 2022
Debt Disclosure [Abstract]
Debt	Debt Long-term debt consists of the following: December 31, 2022 2021 Maturity Balance Weighted- Balance Weighted- (millions) (millions) FPL: First mortgage bonds – fixed 2023-2051 $ 15,790 4.03 % $ 14,290 4.20 % Pollution control, solid waste disposal and industrial development revenue bonds – primarily variable (a) 2023-2052 1,366 3.20 % 1,407 0.15 % Senior unsecured notes – primarily variable (b)(c) 2023-2072 4,042 3.99 % 2,697 1.37 % Other long-term debt – primarily variable (c) 2046 7 7.90 % 307 0.82 % Unamortized debt issuance costs and discount (203) (191) Total long-term debt of FPL 21,002 18,510 Less current portion of long-term debt 1,547 536 Long-term debt of FPL, excluding current portion 19,455 17,974 NEER: NextEra Energy Resources: Senior secured limited-recourse long-term debt – variable (c)(d) 2024-2037 3,582 6.24 % 3,100 1.74 % Senior secured limited-recourse long-term loans – fixed 2028-2052 2,452 3.43 % 2,475 3.30 % Other long-term debt – primarily variable (c)(d) 2026-2048 777 6.33 % 785 2.50 % NEET – long-term debt – primarily fixed (d) 2023-2052 2,348 5.10 % 1,151 2.69 % Unamortized debt issuance costs and premium (108) (92) Total long-term debt of NEER 9,051 7,419 Less current portion of long-term debt 694 664 Long-term debt of NEER, excluding current portion 8,357 6,755 NEECH: Debentures – fixed 2023-2062 17,865 2.99 % 10,990 2.21 % Debentures – variable (c) 2023-2024 2,200 4.14 % 3,850 0.56 % Debentures, related to NEE's equity units – fixed 2025-2027 6,500 2.28 % 6,000 1.46 % Junior subordinated debentures – primarily fixed (d) 2057-2082 3,723 5.23 % 3,723 4.54 % Japanese yen denominated long-term debt – primarily variable (c)(d)(e) 2023-2030 506 0.73 % 582 1.49 % Australian dollar denominated long-term debt – fixed (e) 2026 338 2.20 % 360 2.20 % Other long-term debt – fixed 2023 164 0.92 % 186 0.92 % Other long-term debt – variable (c) 2024 675 5.02 % 1,245 0.64 % Unamortized debt issuance costs, premium (135) (120) Total long-term debt of NEECH 31,836 26,816 Less current portion of long-term debt 4,392 585 Long-term debt of NEECH, excluding current portion 27,444 26,231 Total long-term debt $ 55,256 $ 50,960 ______________________ (a) Includes variable rate tax exempt bonds that permit individual bondholders to tender the bonds for purchase at any time prior to maturity. In the event these variable rate tax exempt bonds are tendered for purchase, they would be remarketed by a designated remarketing agent in accordance with the related indenture. If the remarketing is unsuccessful, FPL would be required to purchase these variable rate tax exempt bonds. At December 31, 2022, these variable rate tax exempt bonds totaled approximately $1,334 million. All variable rate tax exempt bonds tendered for purchase have been successfully remarketed. FPL's syndicated revolving credit facilities are available to support the purchase of the variable rate tax exempt bonds. Variable interest rate is established at various intervals by the remarketing agent. (b) At December 31, 2022, includes approximately $1,327 million of floating rate notes that permit individual noteholders to require repayment at specified dates prior to maturity. FPL’s syndicated revolving credit facilities are available to support the purchase of the floating rate notes. (c) Variable rate is based on an underlying index plus a specified margin. (d) Interest rate contracts, primarily swaps, have been entered into with respect to certain of these debt issuances. See Note 3. (e) Foreign currency contracts have been entered into with respect to these debt issuances. See Note 3. As of December 31, 2022, minimum annual maturities of long - term debt for NEE are approximately $6,633 million, $6,848 million, $7,702 million, $1,218 million and $7,329 million for 2023, 2024, 2025, 2026 and 2027, respectively. The respective amounts for FPL are approximately $1,547 million, $1,646 million, $1,700 million, $0.2 million and $328 million. At December 31, 2022 and 2021, short-term borrowings had a weighted-average interest rate of 4.58% (4.41% for FPL) and 0.39% (0.27% for FPL), respectively. Subsidiaries of NEE, including FPL, had credit facilities with total capacity at December 31, 2022 of approximately $17.9 billion ($4.5 billion for FPL) which provide for the funding of loans and/or issuance of letters of credit. At December 31, 2022, letters of credit outstanding under these credit facilities totaled approximately $3.7 billion ($3.0 million for FPL). There were no borrowings outstanding under these credit facilities at December 31, 2022. At February 17, 2023, NEE, including FPL, had credit facilities with total capacity of approximately $20.2 billion ($4.1 billion for FPL). 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 2022, NEECH completed a remarketing of $1.5 billion aggregate principal amount of its Series J Debentures due September 1, 2024 that were issued in September 2019 as components of equity units issued concurrently by NEE (September 2019 equity units). The debentures are fully and unconditionally guaranteed by NEE. In connection with the remarketing of the debentures, the interest rate on the debentures was reset to 4.255% per year, and interest is payable on March 1 and September 1 of each year, commencing September 1, 2022. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the September 2019 equity units, on September 1, 2022, NEE issued approximately 21.6 million shares of common stock in exchange for $1.5 billion. As a result of the four-for-one stock split of NEE common stock effective October 26, 2020 (2020 stock split) (and adjustments related to the dividend rate), the fixed settlement rates of NEE’s two outstanding series of Corporate Units sold in 2020 have been adjusted as described below. In addition, these two series of 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 these two series of Corporate Units to present the practical effect of the antidilution adjustments as of December 31, 2022. 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, 2022, the number of shares issued per equity unit would (subject to antidilution adjustments) range from 0.7132 shares if the applicable market value of a share of NEE common stock is less than or equal to $70.39 (the adjusted reference price) to 0.5703 shares if the applicable market value of a share is equal to or greater than $87.99 (the adjusted threshold appreciation price), with the applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending February 24, 2023. Total annual distributions on the equity units are at the rate of 5.279%, consisting of interest on the debentures (1.84% per year) and payments under the stock purchase contracts (3.439% per year). The interest rate on the debentures is expected to be reset on or after September 1, 2022. A holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit. The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder's obligation to purchase NEE common stock under the related stock purchase contract. If a successful remarketing does not occur on or before the third business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE. In September 2020, NEE sold $2.0 billion of equity units (initially consisting of Corporate Units). Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series L Debenture due September 1, 2025, issued in the principal amount of $1,000 by NEECH. Each stock purchase contract requires the holder to purchase by no later than September 1, 2023 (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range described in the following sentence. If purchased on the final settlement date, as of December 31, 2022, the number of shares issued per equity unit would (subject to antidilution adjustments) range from 0.6802 shares if the applicable market value of a share of NEE common stock is less than or equal to $73.79 (the adjusted reference price) to 0.5442 shares if the applicable market value of a share is equal to or greater than $92.24 (the adjusted threshold appreciation price), with the applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending August 29, 2023. Total annual distributions on the equity units are at the rate of 6.219%, consisting of interest on the debentures (0.509% per year) and payments under the stock purchase contracts (5.710% per year). The interest rate on the debentures is expected to be reset on or after March 1, 2023. A holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit. The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder's obligation to purchase NEE common stock under the related stock purchase contract. If a successful remarketing does not occur on or before the third business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE. In September 2022, 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 M Debenture due September 1, 2027, 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, 2025 (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, 2022, the number of shares issued per equity unit would (subject to antidilution adjustments) range from 0.5626 shares if the applicable market value of a share of NEE common stock is less than or equal to $88.88 (the reference price) to 0.4500 shares if the applicable market value of a share is equal to or greater than $111.10 (the 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 27, 2025. Total annual distributions on the equity units are at the rate of 6.926%, consisting of interest on the debentures (4.60% per year) and payments under the stock purchase contracts (2.326% per year). The interest rate on the debentures is expected to be reset on or after March 1, 2025. 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, 2022
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, 2022 2021 2020 (millions, except per share amounts) Numerator – net income attributable to NEE $ 4,147 $ 3,573 $ 2,919 Denominator: Weighted-average number of common shares outstanding – basic 1,972.6 1,962.5 1,959.0 Equity units, stock options, performance share awards and restricted stock (a) 6.0 9.7 9.8 Weighted-average number of common shares outstanding – assuming dilution 1,978.6 1,972.2 1,968.8 Earnings per share attributable to NEE: Basic $ 2.10 $ 1.82 $ 1.49 Assuming dilution $ 2.10 $ 1.81 $ 1.48 ______________________ (a) Calculated using the treasury stock method. Performance share awards are included in diluted weighted-average number of common shares outstanding based upon what would be issued if the end of the reporting period was the end of the term of the award. Common shares issuable pursuant to equity units, stock options and/or performance share awards, as well as restricted stock which were not included in the denominator above due to their antidilutive effect were approximately 38.1 million, 30.5 million and 27.1 million for the years ended December 31, 2022, 2021 and 2020, respectively. On September 14, 2020, NEE's board of directors approved a four-for-one split of NEE common stock effective October 26, 2020. NEE's authorized common stock increased from 800 million to 3.2 billion shares. All share and share-based data included in NEE's consolidated financial statements reflect the effect of the 2020 stock split. Potentially Dilutive Securities at NEP – NEP senior unsecured convertible notes, when outstanding, are potentially dilutive securities to NEE. In December 2022, June 2021 and December 2020, NEP issued $500 million, $500 million and $600 million, respectively, principal amount of new senior unsecured convertible notes. Holders of these notes may convert all or a portion of the notes in accordance with the related indenture. Upon conversion, NEP will pay cash up to the principal amount of the notes to be converted and pay or deliver, as the case may be, cash, NEP common units or a combination of cash and common units, at NEP's election, in respect of the remainder, if any, of NEP's conversion obligation in excess of the principal amount of the notes being converted. Common Stock Dividend Restrictions – NEE's charter does not limit the dividends that may be paid on its common stock. FPL's mortgage securing FPL's first mortgage bonds contains provisions which, under certain conditions, restrict the payment of dividends and other distributions to NEE. These restrictions do not currently limit FPL's ability to pay dividends to NEE. Stock-Based Compensation – Net income for the years ended December 31, 2022, 2021 and 2020 includes approximately $142 million, $119 million and $107 million, respectively, of compensation costs and $20 million, $19 million and $21 million, respectively, of income tax benefits related to stock-based compensation arrangements. Compensation cost capitalized for the years ended December 31, 2022, 2021 and 2020 was not material. At December 31, 2022, there were approximately $160 million of unrecognized compensation costs related to nonvested/nonexercisable stock-based compensation arrangements. These costs are expected to be recognized over a weighted-average period of 2.5 years. At December 31, 2022, approximately 81 million shares of common stock were authorized for awards to officers, employees and non-employee directors of NEE and its subsidiaries under NEE's: (a) 2021 Long Term Incentive Plan, (b) 2017 Non-Employee Directors Stock Plan and (c) earlier equity compensation plans under which shares are reserved for issuance under existing grants, but no additional shares are available for grant under the earlier plans. NEE satisfies restricted stock and performance share awards by issuing new shares of its common stock or by purchasing shares of its common stock in the open market. NEE satisfies stock option exercises by issuing new shares of its common stock. NEE generally grants most of its stock-based compensation awards in the first quarter of each year. Restricted Stock and Performance Share Awards – Restricted stock typically vests within three years after the date of grant and is subject to, among other things, restrictions on transferability prior to vesting. The fair value of restricted stock is measured based upon the closing market price of NEE common stock as of the date of grant. Performance share awards are typically payable at the end of a three-year performance period if the specified performance criteria are met. The fair value for the majority of performance share awards is estimated based upon the closing market price of NEE common stock as of the date of grant less the present value of expected dividends, multiplied by an estimated performance multiple which is subsequently trued up based on actual performance. The activity in restricted stock and performance share awards for the year ended December 31, 2022 was as follows: Shares/Units Weighted- Restricted Stock: Nonvested balance, January 1, 2022 1,817,732 $ 68.09 Granted 1,001,259 $ 75.13 Vested (758,006) $ 58.83 Forfeited (68,940) $ 76.65 Nonvested balance, December 31, 2022 1,992,045 $ 77.93 Performance Share Awards: Nonvested balance, January 1, 2022 1,412,149 $ 61.22 Granted 1,597,586 $ 58.67 Vested (1,563,850) $ 56.08 Forfeited (308,803) $ 74.01 Nonvested balance, December 31, 2022 1,137,082 $ 71.17 The weighted-average grant date fair value per share of restricted stock granted for the years ended December 31, 2021 and 2020 was $82.69 and $68.25 respectively. The weighted-average grant date fair value per share of performance share awards granted for the years ended December 31, 2021 and 2020 was $54.82 and $46.09, respectively. The total fair value of restricted stock and performance share awards vested was $175 million, $186 million and $177 million for the years ended December 31, 2022, 2021 and 2020, 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: 2022 2021 2020 Expected volatility (a) 17.91 – 19.37% 17.32 – 17.75% 14.63 – 16.31% Expected dividends 2.32 – 2.50% 2.30 – 2.44% 2.50 – 2.72% Expected term (years) (b) 6.5 7.0 7.0 Risk-free rate 1.91 – 3.85% 0.80 – 1.27% 0.49 – 1.52% ______________________ (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, 2022 was as follows: Shares Weighted- Weighted- Aggregate Balance, January 1, 2022 10,013,312 $ 44.87 Granted 1,304,270 $ 75.28 Exercised (594,220) $ 23.77 Forfeited (23,952) $ 78.33 Balance, December 31, 2022 10,699,410 $ 49.67 5.7 $ 363 Exercisable, December 31, 2022 8,152,185 $ 41.28 4.8 $ 345 The weighted-average grant date fair value of options granted was $10.49, $9.82 and $7.08 per share for the years ended December 31, 2022, 2021 and 2020, respectively. The total intrinsic value of stock options exercised was approximately $37 million, $49 million and $71 million for the years ended December 31, 2022, 2021 and 2020, respectively. Cash received from option exercises was approximately $14 million, $15 million and $30 million for the years ended December 31, 2022, 2021 and 2020, respectively. The tax benefits realized from options exercised were approximately $9 million, $11 million and $17 million for the years ended December 31, 2022, 2021 and 2020, 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, 2019 $ (27) $ 11 $ (114) $ (42) $ 3 $ (169) Other comprehensive income before reclassifications — 12 37 13 1 63 Amounts reclassified from AOCI 12 (a) (3) (b) 2 (c) — — 11 Net other comprehensive income 12 9 39 13 1 74 Less other comprehensive income attributable to noncontrolling interests — — — (7) — (7) Impact of disposal of a business 23 (d) — — (13) (d) — 10 Balances, December 31, 2020 8 20 (75) (49) 4 (92) Other comprehensive income (loss) before reclassifications — (11) 95 (1) 1 84 Amounts reclassified from AOCI 6 (a) (4) (b) 5 (c) — — 7 Net other comprehensive income (loss) 6 (15) 100 (1) 1 91 Less other comprehensive loss attributable to noncontrolling interests — — — 1 — 1 Balances, December 31, 2021 14 5 25 (49) 5 — Other comprehensive income (loss) before reclassifications — (84) (133) (44) 1 (260) Amounts reclassified from AOCI 6 (a) 10 (b) 7 (c) — — 23 Net other comprehensive income (loss) 6 (74) (126) (44) 1 (237) Less other comprehensive loss attributable to noncontrolling interests — — — 19 — 19 Balances, December 31, 2022 $ 20 $ (69) $ (101) $ (74) $ 6 $ (218) Attributable to noncontrolling interests $ — $ — $ — $ (14) $ — $ (14) ______________________ (a) Reclassified to interest expense in NEE's consolidated statements of income. See Note 3 – Income Statement Impact of Derivative Instruments. (b) Reclassified to gains on disposal of investments and other property – net in NEE's consolidated statements of income. (c) Reclassified to other net periodic benefit income in NEE's consolidated statements of income. (d) Reclassified to gains on disposal of businesses/assets – net and interest expense in NEE's consolidated statements of income. See Note 3 – Income Statement Impact of Derivative Instruments and Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Commitments – NEE and its subsidiaries have made commitments in connection with a portion of their projected capital expenditures. Capital expenditures at FPL include, among other things, the cost for construction of additional facilities and equipment to meet customer demand, as well as capital improvements to and maintenance of existing facilities. At NEER, capital expenditures include, among other things, the cost, including capitalized interest, for development, construction and maintenance of its competitive energy businesses. Also see Note 4 – Contingent Consideration and Note 6 – RNG Acquisition. At December 31, 2022, estimated capital expenditures, on an accrual basis, for 2023 through 2027 were as follows: 2023 2024 2025 2026 2027 Total (millions) FPL: Generation: (a) New (b) $ 3,060 $ 2,315 $ 2,820 $ 3,670 $ 3,150 $ 15,015 Existing 1,615 1,175 1,045 1,280 1,465 6,580 Transmission and distribution (c) 3,545 3,975 3,645 3,340 3,575 18,080 Nuclear fuel 125 160 200 200 225 910 General and other 675 455 515 385 525 2,555 Total $ 9,020 $ 8,080 $ 8,225 $ 8,875 $ 8,940 $ 43,140 NEER: (d) Wind (e) $ 2,650 $ 1,095 $ 315 $ 20 $ 20 $ 4,100 Solar (f) 4,020 1,145 225 — — 5,390 Other clean energy (g) 1,175 350 55 75 45 1,700 Nuclear, including nuclear fuel 95 215 145 260 285 1,000 Rate-regulated transmission 170 65 45 10 10 300 Other 765 180 95 115 60 1,215 Total $ 8,875 $ 3,050 $ 880 $ 480 $ 420 $ 13,705 ______________________ (a) Includes AFUDC of approximately $105 million, $105 million, $90 million, $125 million and $115 million for 2023 through 2027, respectively. (b) Includes land, generation structures, transmission interconnection and integration and licensing. (c) Includes AFUDC of approximately $60 million, $50 million, $55 million, $30 million and $30 million for 2023 through 2027, respectively. (d) Represents capital expenditures for which applicable internal approvals and also, if required, regulatory approvals have been received. (e) Consists of capital expenditures for new wind projects and repowering of existing wind projects totaling approximately 2,955 MW, and related transmission. (f) Includes capital expenditures for new solar projects (including solar plus battery storage projects) totaling approximately 6,618 MW and related transmission. (g) Includes capital expenditures primarily for battery storage projects and renewable fuels projects. The above estimates are subject to continuing review and adjustment and actual capital expenditures may vary significantly from these estimates. For example, the timing and ultimate cost associated with solar capital expenditures may vary due to supply chain disruptions from Southeast Asian locations. 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 $495 million at December 31, 2022. These obligations primarily related to guaranteeing the residual value of certain financing leases. Payment guarantees and related contracts with respect to unconsolidated entities for which NEE or one of its subsidiaries are the guarantor are recorded at fair value and are included in noncurrent other liabilities on NEE’s consolidated balance sheets. Management believes that the exposure associated with these guarantees is not material. Contracts – In addition to the commitments made in connection with the estimated capital expenditures included in the table in Commitments above, FPL has firm commitments under long-term contracts primarily for the transportation of natural gas with expiration dates through 2042. At December 31, 2022, NEER has entered into contracts with expiration dates through 2033 primarily for the purchase of wind turbines, wind towers and solar modules and related construction and development activities, as well as for the supply of uranium, and the conversion, enrichment and fabrication of nuclear fuel. Approximately $3.7 billion of related commitments are included in the estimated capital expenditures table in Commitments above. In addition, NEER has contracts primarily for the transportation and storage of natural gas with expiration dates through 2041. The required capacity and/or minimum payments under contracts, including those discussed above at December 31, 2022, were estimated as follows: 2023 2024 2025 2026 2027 Thereafter (millions) FPL (a) $ 1,040 $ 970 $ 940 $ 930 $ 850 $ 8,075 NEER (b)(c)(d) $ 2,995 $ 1,145 $ 135 $ 90 $ 80 $ 510 _______________________ (a) Includes approximately $410 million, $410 million, $405 million, $400 million, $400 million and $5,560 million in 2023 through 2027 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 $418 million, $419 million and $386 million for the years ended December 31, 2022, 2021 and 2020, respectively, of which $102 million, $105 million and $108 million, respectively, were eliminated in consolidation at NEE. (b) Excludes commitments related to equity contributions and a 20-year natural gas transportation agreement (approximately $70 million per year) with a joint venture, in which NEER has a 32.2% equity investment, that is constructing a natural gas pipeline. These commitments are subject to the completion of construction of the pipeline which has a very low probability of completion. See Note 4 – Nonrecurring Fair Value Measurements . (c) Includes approximately $260 million of commitments to invest in technology and other investments through 2031. See Note 9 – Other. (d) Includes approximately $205 million, $865 million, $5 million, $5 million, $0 million and $0 million for 2023 through 2027 and thereafter, respectively, of joint obligations of NEECH and NEER. Insurance – Liability for accidents at nuclear power plants is governed by the Price-Anderson Act, which limits the liability of nuclear reactor owners to the amount of insurance available from both private sources and an industry retrospective payment plan. In accordance with this Act, NEE maintains $450 million of private liability insurance per site, which is the maximum obtainable, except at Duane Arnold which obtained an exemption from the NRC and maintains a $100 million private liability insurance limit. Each site, except Duane Arnold, participates in a secondary financial protection system, which provides up to $13.2 billion of liability insurance coverage per incident at any nuclear reactor in the U.S. Under the secondary financial protection system, NEE is subject to retrospective assessments of up to $963 million ($550 million for FPL), plus any applicable taxes, per incident at any nuclear reactor in the U.S., payable at a rate not to exceed $143 million ($82 million for FPL) per incident per year. NextEra Energy Resources and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook and St. Lucie Unit No. 2, which approximates $16 million and $20 million, plus any applicable taxes, per incident, respectively. NEE participates in a nuclear insurance mutual company that provides $2.75 billion of limited insurance coverage per occurrence per site for property damage, decontamination and premature decommissioning risks at its nuclear plants and a sublimit of $1.5 billion for non-nuclear perils, except for Duane Arnold which has a limit of $50 million for property damage, decontamination risks and non-nuclear perils. NEE participates in co-insurance of 10% of the first $400 million of losses per site per occurrence, except at Duane Arnold. The proceeds from such insurance, however, must first be used for reactor stabilization and site decontamination before they can be used for plant repair. NEE also participates in an insurance program that provides limited coverage for replacement power costs if a nuclear plant is out of service for an extended period of time because of an accident. In the event of an accident at one of NEE's or another participating insured's nuclear plants, NEE could be assessed up to $158 million ($101 million for FPL), plus any applicable taxes, in retrospective premiums in a policy year. NextEra Energy Resources and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook, Duane Arnold and St. Lucie Unit No. 2, which approximates $2 million, $2 million and $4 million, plus any applicable taxes, respectively. Due to the high cost and limited coverage available from third-party insurers, NEE does not have property insurance coverage for a substantial portion of either its transmission and distribution property or natural gas pipeline assets. If FPL's storm restoration costs exceed the storm reserve, such storm restoration costs may be recovered, subject to prudence review by the FPSC, through surcharges approved by the FPSC or through securitization provisions pursuant to Florida law. See Note 1 – Storm Funds, Storm Reserves and Storm Cost Recovery. In the event of a loss, the amount of insurance available might not be adequate to cover property damage and other expenses incurred. Uninsured losses and other expenses, to the extent not recovered from customers in the case of FPL, would be borne by NEE and FPL and could have a material adverse effect on NEE's and FPL's financial condition, results of operations and liquidity.

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2022
Segment Reporting [Abstract]
Segment Information	Segment InformationThe tables below present information for NEE's two reportable segments, FPL, a rate-regulated utility business, and NEER, which is comprised of competitive energy and rate-regulated transmission businesses. Corporate and Other represents other business activities, includes eliminating entries, and may include the net effect of rounding. Effective January 1, 2022, the previous segments known as the FPL segment and Gulf Power are no longer separate reportable segments. See Note 1 – Basis of Presentation and Note 6 – Merger of FPL and Gulf Power Company. Prior year amounts for FPL and Corporate and Other were retrospectively adjusted to reflect this segment change. See Note 2 for information regarding NEE's and FPL's operating revenues. NEE's segment information is as follows: 2022 FPL NEER (a) Corp. and NEE (millions) Operating revenues $ 17,282 $ 3,720 $ (46) $ 20,956 Operating expenses – net $ 11,992 (b) $ 5,140 $ 265 $ 17,397 Gains (losses) on disposal of businesses/assets – net $ 4 $ 536 $ (18) $ 522 Interest expense $ 768 $ 128 $ (311) $ 585 Depreciation and amortization $ 2,695 $ 1,722 $ 86 $ 4,503 Equity in earnings of equity method investees $ — $ 202 $ 1 $ 203 Income tax expense (benefit) $ 947 (c) $ (391) (c) $ 30 $ 586 Net income (loss) $ 3,701 $ (616) $ 161 $ 3,246 Net loss attributable to noncontrolling interests $ — $ 901 $ — $ 901 Net income attributable to NEE $ 3,701 $ 285 $ 161 $ 4,147 Capital expenditures, independent power and other investments and nuclear fuel purchases $ 9,185 $ 9,645 $ 453 $ 19,283 Property, plant and equipment – net $ 64,693 $ 45,840 $ 526 $ 111,059 Total assets $ 86,559 $ 70,713 $ 1,663 $ 158,935 Investment in equity method investees $ — $ 6,572 $ 10 $ 6,582 _________________________ (a) Interest expense allocated from NEECH to NextEra Energy Resources' subsidiaries 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) FPL's income statement line for total operating expenses – net includes gains (losses) on disposal of businesses/assets – net. (c) Includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 – Income Taxes. 2021 FPL NEER (a) Corp. and NEE (millions) Operating revenues $ 14,102 $ 3,053 $ (86) $ 17,069 Operating expenses – net $ 9,587 (b) $ 4,434 $ 212 $ 14,233 Gains (losses) on disposal of businesses/assets – net $ 1 $ 78 $ (2) $ 77 Interest expense $ 615 $ 367 $ 288 $ 1,270 Depreciation and amortization $ 2,266 $ 1,576 $ 82 $ 3,924 Equity in earnings of equity method investees $ — $ 666 $ — $ 666 Income tax expense (benefit) $ 838 $ (395) (c) $ (95) $ 348 Net income (loss) $ 3,206 $ (147) $ (232) $ 2,827 Net loss attributable to noncontrolling interests $ — $ 746 $ — $ 746 Net income (loss) attributable to NEE $ 3,206 $ 599 $ (232) $ 3,573 Capital expenditures, independent power and other investments and nuclear fuel purchases $ 7,570 $ 8,363 $ 144 $ 16,077 Property, plant and equipment – net $ 58,227 $ 40,900 $ 221 $ 99,348 Total assets $ 78,067 $ 62,113 $ 732 $ 140,912 Investment in equity method investees $ — $ 6,150 $ 9 $ 6,159 _________________________ (a) Interest expense allocated from NEECH to NextEra Energy Resources' subsidiaries 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) FPL's income statement line for total operating expenses – net includes gains (losses) on disposal of businesses/assets – net. (c) Includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 – Income Taxes. 2020 FPL NEER (a) Corp. and NEE (millions) Operating revenues $ 13,060 $ 5,046 $ (109) $ 17,997 Operating expenses – net $ 8,940 $ 4,125 $ 169 $ 13,234 Gains (losses) on disposal of businesses/assets – net $ — $ 363 $ (10) $ 353 Interest expense $ 641 $ 659 $ 650 $ 1,950 Depreciation and amortization $ 2,526 $ 1,460 $ 66 $ 4,052 Equity in losses of equity method investees $ — $ (1,351) $ — $ (1,351) Income tax expense (benefit) $ 678 $ (416) (b) $ (218) $ 44 Net income (loss) $ 2,890 $ (19) $ (502) $ 2,369 Net loss attributable to noncontrolling interests $ — $ 550 $ — $ 550 Net income (loss) attributable to NEE $ 2,890 $ 531 $ (502) $ 2,919 Capital expenditures, independent power and other investments and nuclear fuel purchases $ 7,679 $ 6,893 $ 38 $ 14,610 Property, plant and equipment – net $ 53,879 $ 37,842 $ 82 $ 91,803 Total assets $ 71,001 $ 55,633 $ 1,050 $ 127,684 Investment in equity method investees $ — $ 5,713 $ 15 $ 5,728 _________________________ (a) Interest expense allocated from NEECH to NextEra Energy Resources' subsidiaries 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) Includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 – Income Taxes.

Summary of Significant Accoun_2

Summary of Significant Accounting and Reporting Policies (Policies)	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation – The operations of NextEra Energy, Inc. (NEE) are conducted primarily through Florida Power & Light Company (FPL), a wholly owned subsidiary, and NextEra Energy Resources, LLC (NextEra Energy Resources) and NextEra Energy Transmission, LLC (NEET) (collectively, NEER), wholly owned indirect subsidiaries that are combined for segment reporting purposes. On January 1, 2021, FPL and Gulf Power Company merged, with FPL as the surviving entity. However during 2021, FPL continued to be regulated as two separate ratemaking entities in the former service areas of FPL and Gulf Power. Effective January 1, 2022, FPL became regulated as one electric ratemaking entity with new unified rates and tariffs, and also became one reportable segment of NEE (see Rate Regulation – Base Rates Effective January 2022 through December 2025 below). As a result, the previous segments known as the FPL segment and Gulf Power are no longer separate reportable segments. See Note 16. FPL's principal business is a rate-regulated electric utility which supplies electric service to approximately 5.8 million customer accounts throughout most of the east and lower west coasts of Florida and eight counties throughout northwest Florida. NEER invests in independent power projects through both controlled and consolidated entities and noncontrolling owner ship interests in joint ventures. NEER participates in natural gas, natural gas liquids and oil production primarily through operating and non-operating ownership interests and in pipeline infrastructure through either wholly owned subsidiaries or noncontrolling or joint venture interests. NEER also invests in rate-regulated transmission facilities and transmission lines that connect its electric generation facilities to the electric grid through controlled and consolidated entities. The consolidated financial statements of NEE and FPL include the accounts of their respective controlled subsidiaries. They also include NEE's and FPL's share of the undivided interest in certain assets, liabilities, revenues and expenses. Amounts representing NEE's interest in entities it does not control, but over which it exercises significant influence, are included in investment in equity method investees; the earnings/losses of these entities is included in equity in earnings (losses) of equity method investees. Intercompany balances and transactions have been eliminated in consolidation. Certain amounts included in prior years' consolidated financial statements have been reclassified to conform to the current year's presentation. The preparation of financial statements requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of c ontingent assets and liabilities. Actual results could differ from those estimates.
NextEra Energy Partners, LP	NextEra Energy Partners, LP (NEP) was formed in 2014 to acquire, manage and own contracted clean energy projects with stable long-term cash flows through a limited partner interest in NextEra Energy Operating Partners, LP (NEP OpCo). NEP owns or has an ownership interest in a portfolio of wind, solar and solar plus battery storage projects and long-term contracted natural gas pipelines. NEE owns a noncontrolling interest in NEP, accounts for its ownership interest in NEP as an equity method investment with its earnings/losses from NEP as equity in earnings (losses) of equity method investees and accounts for NextEra Energy Resources' project sales to NEP as third-party sales in its consolidated financial statements. NEER operates essentially all of the energy projects owned by NEP and provides services to NEP under various related party operations and maintenance, administrative and management services agreements.
Operating Revenues	Operating Revenues – FPL and NEER generate substantially all of NEE’s operating revenues, which primarily include revenues from contracts with customers as further discussed in Note 2 , as well as, at NEER, derivative and lease transactions. FPL's operating revenues include amounts resulting from base rates, cost recovery clauses (see Rate Regulation below), franchise fees, gross receipts taxes and surcharges related to storms (see Storm Funds, Storm Reserves and Storm Cost Recovery below). Franchise fees and gross receipts taxes are imposed on FPL; however, the Florida Public Service Commission (FPSC) allows FPL to include in the amounts charged to customers the amount of the gross receipts tax for all customers and the franchise fee for those customers located in the jurisdiction that imposes the amount. Accordingly, FPL's franchise fees and gross receipts taxes are reported gross in operating revenues and taxes other than income taxes and other in NEE's and FPL's consolidated statements of income and were approximately $1,035 million, $852 million and $800 million in 2022, 2021 and 2020, respectively. FPL also collects municipal utility taxes which are reported gross in customer receivables and accounts payable on NEE's and FPL's consolidated balance sheets. Certain NEER commodity contracts for the purchase and sale of power that meet the definition of a derivative are recorded at fair value with subsequent changes in fair value recognized as revenue. See Energy Trading below and Note 3.
Rate Regulation	Rate Regulation – FPL, the most significant of NEE's rate-regulated subsidiaries, is subject to rate regulation by the FPSC and the Federal Energy Regulatory Commission (FERC). Its rates are designed to recover the cost of providing service to its customers including a reasonable rate of return on invested capital. As a result of this cost-based regulation, FPL follows the accounting guidance that allows regulators to create assets and impose liabilities that would not be recorded by non-rate regulated entities. Regulatory assets and liabilities represent probable future revenues that will be recovered from or refunded to customers through the ratemaking process. NEE's and FPL's regulatory assets and liabilities are as follows: NEE FPL December 31, December 31, 2022 2021 2022 2021 (millions) Regulatory assets: Current: Early retirement of generation facilities and transmission assets (a) $ 145 $ 140 $ 145 $ 140 Acquisition of purchased power agreements (b) 141 141 141 141 Deferred clause and franchise expenses 919 (c) 698 919 (c) 698 Storm restoration costs 911 (d) 92 911 (d) 92 Other 49 54 39 40 Total $ 2,165 $ 1,125 $ 2,155 $ 1,111 Noncurrent: Early retirement of generation facilities and transmission assets (a) $ 2,026 $ 2,233 $ 2,026 $ 2,233 Acquisition of purchased power agreements (b) 191 332 191 332 Deferred clause expenses 1,227 (c) 17 1,227 (c) 17 Storm restoration costs 326 (d) 150 326 (d) 150 Accrued asset removal costs (e) 532 263 532 263 Other 1,690 1,583 1,182 1,348 Total $ 5,992 $ 4,578 $ 5,484 $ 4,343 Regulatory liabilities: Current: Deferred clause revenues $ 339 $ 274 $ 339 $ 274 Other 11 15 10 4 Total $ 350 $ 289 $ 349 $ 278 Noncurrent: Asset retirement obligation regulatory expense difference $ 3,323 $ 4,290 $ 3,323 $ 4,290 Accrued asset removal costs (e) 658 782 623 752 Deferred taxes 4,233 4,561 4,129 4,457 Other 1,412 1,640 1,383 1,554 Total $ 9,626 $ 11,273 $ 9,458 $ 11,053 ______________________ (a) The majority of these regulatory assets are being amortized over 20 years. (b) The majority of these regulatory assets are being amortized over approximately 9 years. (c) The majority of these regulatory assets are expected to be amortized over 21 months beginning April 2023. See below regarding the 2022 fuel under-recovery. (d) The majority of these regulatory assets are expected to be amortized over 12 months beginning April 2023. See Storm Funds, Storm Reserves and Storm Cost Recovery below. (e) See Electric Plant, Depreciation and Amortization below. Cost recovery clauses, which are designed to permit full recovery of certain costs and provide a return on certain assets allowed to be recovered through various clauses, include substantially all fuel, purchased power and interchange expense, costs associated with an FPSC-approved transmission and distribution storm protection plan, certain costs associated with the acquisition and retirement of several electric generation facilities, certain construction-related costs for certain of FPL's solar generation facilities, and conservation and certain environmental-related costs. Revenues from cost recovery clauses are recorded when billed; FPL achieves matching of costs and related revenues by deferring the net under-recovery or over-recovery. Any under-recovered costs or over-recovered revenues are collected from or returned to customers in subsequent periods. In January 2023, FPL filed a petition with the FPSC requesting recovery of its 2022 fuel under-recovery of approximately $2.1 billion (included in current deferred clause and franchise expenses and noncurrent deferred clause expenses above) over 21 months beginning April 2023. As a result of natural gas prices currently being lower than originally projected for 2023, FPL also requested a $1.0 billion mid-course correction to reduce the 2023 levelized fuel charges to customers that would go into effect beginning April 2023. An FPSC decision is expected in March 2023.
Electric Plant, Depreciation and Amortization	Electric Plant, Depreciation and Amortization – The cost of additions to units of property of FPL and NEER is added to electric plant in service and other property. In accordance with regulatory accounting, the cost of FPL's units of utility property retired, less estimated net salvage value, is charged to accumulated depreciation. Maintenance and repairs of property as well as replacements and renewals of items determined to be less than units of utility property are charged to other operations and maintenance (O&M) expenses. The American Recovery and Reinvestment Act of 2009, as amended, provided for an option to elect a cash grant (convertible investment tax credits (ITCs)) for certain renewable energy property (renewable property). Convertible ITCs are recorded as a reduction in property, plant and equipment on NEE's and FPL's consolidated balance sheets and are amortized as a reduction to depreciation and amortization expense over the estimated life of the related property. At December 31, 2022 and 2021, convertible ITCs, net of amortization, were approximately $693 million ($111 million at FPL) and $755 million ($116 million at FPL). Depreciation of FPL's electric property is provided on a straight-line basis, primarily over its average remaining useful life. FPL includes in depreciation expense a provision for electric generation plant dismantlement, interim asset removal costs, accretion related to asset retirement obligations (see Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below) and storm recovery amortization. For substantially all of FPL's property, depreciation studies are performed periodically and filed with the FPSC which result in updated depreciation rates. As part of the 2021 rate agreement, the FPSC approved new unified depreciation rates which became effective January 1, 2022. Reserve amortization is recorded as either an increase or decrease to accrued asset removal costs which is reflected in noncurrent regulatory assets on NEE's and FPL's consolidated balance sheets. FPL files a twelve-month forecast with the FPSC each year which contains a regulatory ROE intended to be earned based on the best information FPL has at that time assuming normal weather. This forecast establishes a targeted regulatory ROE. In order to earn the targeted regulatory ROE in each reporting period subject to the conditions of the effective rate agreement, reserve amortization is calculated using a trailing thirteen-month average of retail rate base and capital structure in conjunction with the trailing twelve months regulatory retail base net operating income, which primarily includes the retail base portion of base and other revenues, net of O&M, depreciation and amortization, interest and tax expenses. In general, the net impact of these income statement line items is adjusted, in part, by reserve amortization or its reversal to earn the targeted regulatory ROE. See Rate Regulation – Base Rates Effective January 2022 through December 2025 above. NEER's electric plant in service and other property less salvage value, if any, are depreciated primarily using the straight-line method over their estimated useful lives. NEER reviews the estimated useful lives of its fixed assets on an ongoing basis. NEER's oil and gas production assets are accounted for under the successful efforts method. Depletion expenses for the acquisition of reserve rights and development costs are recognized using the unit of production method.
Nuclear Fuel	Nuclear Fuel – FPL and NEER have several contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel. See Note 15 – Contracts. FPL's and NEER's nuclear fuel costs are charged to fuel expense on a unit of production method.
Construction Activity	Construction Activity – Allowance for funds used during construction (AFUDC) is a noncash item which represents the allowed cost of capital, including an ROE, used to finance construction projects. FPL records the portion of AFUDC attributable to borrowed funds as a reduction of interest expense and the remainder as other income. FPSC rules limit the recording of AFUDC to projects that have an estimated cost in excess of 0.5% prior to 2021 and 0.4% beginning in 2021 of a utility's plant in service balance and require more than one year to complete. FPSC rules allow construction projects below the applicable threshold as a component of rate base. FPL's construction work in progress includes construction materials, progress payments on major equipment contracts, engineering costs, AFUDC and other costs directly associated with the construction of various projects. Upon completion of the projects, these costs are transferred to electric utility plant in service and other property. Capitalized costs associated with construction activities are charged to O&M expenses when recoverability is no longer probable. NEER capitalizes project development costs once it is probable that such costs will be realized through the ultimate construction of the related asset or sale of development rights. At December 31, 2022 and 2021, NEER's capitalized development costs totaled approximately $1,027 million and $831 million, respectively, which are included in noncurrent other assets on NEE's consolidated balance sheets. These costs include land rights and other third-party costs directly associated with the development of a new project. Upon commencement of construction, these costs either are transferred to construction work in progress or remain in other assets, depending upon the nature of the cost. Capitalized development costs are charged to O&M expenses when it is probable that these costs will not be realized.
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 allocated to a regulatory liability or regulatory asset using a systematic and rational method over the asset's estimated useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the ARO and a decrease in the regulatory liability or regulatory asset. Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the ARO and asset retirement cost, or regulatory liability when asset retirement cost is depleted. For NEE's non-rate regulated operations, the asset retirement cost is allocated to expense using a systematic and rational method over the asset's estimated useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense, which is included in depreciation and amortization expense in NEE's consolidated statements of income. Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the asset retirement cost, or income when asset retirement cost is depleted.
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs	Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs – For ratemaking purposes, FPL accrues for the cost of end of life retirement and disposal of its nuclear and other generation plants over the expected service life of each unit based on nuclear decommissioning and other generation dismantlement studies periodically filed with the FPSC. In addition, FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC. As approved by the FPSC, FPL previously suspended its annual decommissioning accrual. Any differences between expense recognized for financial reporting purposes and the amount recovered through rates are reported as a regulatory asset or liability in accordance with regulatory accounting. See Rate Regulation, Electric Plant, Depreciation and Amortization, and Asset Retirement Obligations above and Note 11. Nuclear decommissioning studies are performed at least every five years and are filed with the FPSC for approval. FPL filed updated nuclear decommissioning studies with the FPSC in December 2020. These studies reflect, among other things, the expiration dates of the operating licenses for FPL's nuclear units at the time of the studies. The 2020 studies provide for the dismantlement of Turkey Point Units Nos. 3 and 4 following the end of plant operation with decommissioning activities commencing in 2052 and 2053, respectively, however, in 2022, the U.S. Nuclear Regulatory Commission (NRC) amended Turkey Point Units Nos. 3 and 4 license renewals by removing the 20 additional years of operation reflected in the studies. FPL filed a site-specific environmental impact statement with the NRC related to the previously approved 20-year renewal application for both Turkey Point operating licenses. Approval of the additional 20 years of operations is pending. The studies filed in 2020 also provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the dismantlement of St. Lucie Unit No. 2 in 2043. These studies also assume that FPL will be storing spent fuel on site pending removal to a United States (U.S.) government facility. FPL's portion of the ultimate costs of decommissioning its four nuclear units, including costs associated with spent fuel storage above what is expected to be refunded by the U.S. Department of Energy (DOE) under a spent fuel settlement agreement, is estimated to be approximately $9.6 billion, or $2.5 billion expressed in 2022 dollars. The ultimate costs of decommissioning reflect the applications submitted to the NRC for the extension of Turkey Point Units Nos. 3 and 4 and St. Lucie Units Nos. 1 and 2 licenses for an additional 20 years. Restricted funds for the payment of future expenditures to decommission FPL's nuclear units are included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's and FPL's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily carried at fair value. See Note 4. Fund earnings, consisting of dividends, interest and realized gains and losses, net of taxes, are reinvested in the funds. Fund earnings, as well as any changes in unrealized gains and losses and estimated credit losses on debt securities, are not recognized in income and are reflected as a corresponding offset in the related regulatory asset or liability accounts. FPL does not currently make contributions to the decommissioning funds, other than the reinvestment of fund earnings. During 2022, 2021 and 2020 fund earnings on decommissioning funds were approximately $58 million, $173 million and $132 million, respectively. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. Other generation plant dismantlement studies are performed periodically and are submitted to the FPSC for approval. Previously approved studies were effective from January 1, 2017 through December 2021 and resulted in an annual expense of $26 million which is recorded in depreciation and amortization expense in NEE's and FPL's consolidated statements of income. As part of the 2021 rate agreement, the FPSC approved a new annual expense of $48 million based on FPL's updated dismantlement studies which became effective January 1, 2022. At December 31, 2022, FPL's portion of the ultimate cost to dismantle its other generation units is approximately $2.4 billion, or $1.2 billion expressed in 2022 dollars. NEER's AROs primarily include nuclear decommissioning liabilities for Seabrook Station (Seabrook), Duane Arnold Energy Center (Duane Arnold) and Point Beach Nuclear Power Plant (Point Beach) and dismantlement liabilities for its wind and solar facilities. The liabilities are being accreted using the interest method through the date decommissioning or dismantlement activities are expected to be complete. See Note 11. At December 31, 2022 and 2021, NEER's ARO was approximately $1.2 billion and $1.1 billion, respectively, and was primarily determined using various internal and external data and applying a probability percentage to a variety of scenarios regarding the life of the plant and timing of decommissioning or dismantlement. NEER's portion of the ultimate cost of decommissioning its nuclear plants, including costs associated with spent fuel storage above what is expected to be refunded by the DOE under a spent fuel settlement agreement, is estimated to be approximately $9.5 billion, or $2.0 billion expressed in 2022 dollars. The ultimate cost to dismantle NEER's wind and solar facilities is estimated to be approximately $2.5 billion. Seabrook files a comprehensive nuclear decommissioning study with the New Hampshire Nuclear Decommissioning Financing Committee (NDFC) every four years; the most recent study was filed in 2019. Seabrook's decommissioning funding plan is also subject to annual review by the NDFC. Currently, there are no ongoing decommissioning funding requirements for Seabrook, Duane Arnold and Point Beach, however, the NRC, and in the case of Seabrook, the NDFC, has the authority to require additional funding in the future. NEER's portion of Seabrook's, Duane Arnold's and Point Beach's restricted funds for the payment of future expenditures to decommission these plants is included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily carried at fair value. See Note 4. Market adjustments for debt securities result in a corresponding adjustment to other comprehensive income (OCI), except for estimated credit losses and unrealized losses on debt securities intended or required to be sold prior to recovery of the amortized cost basis, which are recognized in other – net in NEE's consolidated statements of income. Market adjustments for equity securities are recorded in change in unrealized gains (losses) on equity securities held in NEER's nuclear decommissioning funds – net in NEE's consolidated statements of income. Fund earnings, consisting of dividends, interest and realized gains and losses are recognized in income and are reinvested in the funds. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes.
Major Maintenance Costs	Major Maintenance Costs – FPL expenses costs associated with planned maintenance for its non-nuclear electric generation plants as incurred. FPL recognizes costs associated with planned major nuclear maintenance in accordance with regulatory treatment. FPL defers nuclear maintenance costs for each nuclear unit’s planned outage to a regulatory asset as the costs are incurred. FPL amortizes the costs to O&M expense using the straight-line method over the period from the end of the current outage to the next planned outage where the respective work scope is performed.
Cash Equivalents	Cash Equivalents – Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less.
Restricted Cash	Restricted Cash – At December 31, 2022 and 2021, NEE had approximately $1,840 million ($33 million for FPL) and $677 million ($53 million for FPL), respectively, of restricted cash, which is included in current other assets on NEE's and FPL's consolidated balance sheets. Restricted cash is primarily related to debt service payments and margin cash collateral requirements at NEER and bond proceeds held for construction at FPL. In addition, where offsetting positions exist, restricted cash related to margin cash collateral of $7 million is netted against derivative assets and $1,541 million is netted against derivative liabilities at December 31, 2022 and $121 million is netted against derivative assets and $172 million is netted against derivative liabilities at December 31, 2021. See Note 3.
Measurement of Credit Losses on Financial Instruments	Measurement of Credit Losses on Financial Instruments – Effective January 1, 2020, NEE and FPL adopted an accounting standards update that provides for a new methodology, the current expected credit loss (CECL) model, to account for credit losses for certain financial assets measured at amortized cost. On January 1, 2020, NEE recorded a reduction to retained earnings of approximately $11 million representing the cumulative effect of adopting the new standards update, which primarily related to the impact of applying the CECL model to NEER's receivables. The impact of adopting the new standards update was not material to FPL.
Allowance for Doubtful Accounts	Allowance for Doubtful Accounts and Bad Debt – FPL maintains an accumulated provision for uncollectible customer accounts receivable that is estimated using a percentage, derived from historical revenue and write-off trends, of the previous four months of revenue, and includes estimates of credit and other losses based on both current events and forecasts. NEER regularly reviews collectibility of its receivables and establishes a provision for losses estimated as a percentage of accounts receivable based on the historical bad debt write-off trends for its retail electricity provider operations, as well as includes estimates for credit and other losses based on both current events and forecasts. When necessary, NEER uses the specific identification method for all other receivables. Credit Losses – NEE's credit department monitors current and forward credit exposure to counterparties and their affiliates. Prospective and existing customers are reviewed for creditworthiness based on established standards and credit quality indicators. Credit quality indicators and standards that are closely monitored include credit ratings, certain financial ratios and delinquency trends which are based off the latest available information. Customers not meeting minimum standards provide various credit enhancements or secured payment terms, such as letters of credit, the posting of margin cash collateral or use of master netting arrangements. For the years ended December 31, 2022, 2021 and 2020, NEE recorded approximately $113 million, $146 million and $94 million of bad debt expense, including credit losses, respectively, which are included in O&M expenses in NEE’s consolidated statements of income. The amounts recorded in 2021 primarily relate to credit losses at NEER driven by the operational and energy market impacts of severe prolonged winter weather in Texas in February 2021 (February 2021 weather event). The estimate for credit losses related to the impacts of the February 2021 weather event was developed based on NEE’s assessment of the ultimate collectability of these receivables. At December 31, 2021, approximately $127 million of allowances were included in noncurrent other assets on NEE's consolidated balance sheet related to the February 2021 weather event. During 2022, the net receivable was settled.
Inventory	Inventory – FPL values materials, supplies and fuel inventory using a weighted-average cost method. NEER's materials, supplies and fuel inventories, which include emissions allowances and renewable energy credits, are carried at the lower of weighted-average cost and net realizable value, unless evidence indicates that the weighted-average cost will be recovered with a normal profit upon sale in the ordinary course of business.
Energy Trading	Energy Trading – NEE provides full energy and capacity requirements services primarily to distribution utilities, which include load-following services and various ancillary services, in certain markets and engages in power and fuel marketing and trading activities to optimize the value of electricity and fuel contracts, generation facilities and gas infrastructure assets, as well as to take advantage of projected favorable commodity price movements. Trading contracts that meet the definition of a derivative are accounted for at fair value and realized gains and losses from all trading contracts, including those where physical delivery is required, are recorded net for all periods presented. See Note 3.
Storm Funds, Storm Reserves and Storm Cost Recovery	Storm Funds, Storm Reserves and Storm Cost Recovery – The storm funds provide coverage toward FPL's storm damage costs. Marketable securities held in the storm funds are carried at fair value. See Note 4. Fund earnings, consisting of dividends, interest and realized gains and losses, net of taxes, are reinvested in the funds. Fund earnings, as well as any changes in unrealized gains and losses, are not recognized in income and are reflected as a corresponding adjustment to the storm reserve. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. The storm funds are included in special use funds and the storm reserves in noncurrent regulatory liabilities, or in the case of a deficit, in regulatory assets on NEE's and FPL's consolidated balance sheets. During 2022, FPL’s service area was impacted by Hurricane Ian in September and Hurricane Nicole in November which resulted in total recoverable storm restoration costs of approximately $1.3 billion. Prior to Hurricane Ian, FPL’s storm reserve had a balance of approximately $220 million. At December 31, 2022, the recoverable storm restoration costs associated with Hurricane Ian and Hurricane Nicole exceeded the balance of the storm reserve by approximately $1.1 billion. This deficit has been recorded by FPL as current and noncurrent regulatory assets on NEE’s and FPL’s December 31, 2022 consolidated balance sheets. In January 2023, FPL filed a petition with the FPSC requesting the recovery of eligible storm restoration costs over the reserve amount, plus approximately $220 million to replenish the reserve, through an interim surcharge that would apply for a 12-month period beginning April 1, 2023. While a 12-month recovery period would reduce the potential bill impacts in the event of 2023 storm activity, the FPSC may approve a longer recovery period. The amount collected will be subject to refund based on an FPSC prudence review. In addition, FPL also provided information that incorporates the remaining unrecovered pre-2022 northwest Florida service area storm restoration costs (see below for a discussion of such costs), estimated to be approximately $136 million at April 1, 2023, into the interim surcharge discussed above. The unpaid portion of the storm restoration costs at December 31, 2022, of approximately $618 million, including estimated capital costs, is included in other current liabilities on NEE’s and FPL’s consolidated balance sheet. During 2021 and 2020, FPL’s service area was impacted by hurricanes and tropical storms, which resulted in the recording of incremental storm restoration costs. FPL determined that it would not seek recovery of certain of such costs associated with the 2016 rate agreement through a storm surcharge from customers and instead recorded approximately $28 million and $183 million in 2021 and 2020, respectively, as storm restoration costs in NEE's and FPL’s consolidated statements of income (included in O&M expenses). FPL used available reserve amortization to offset all such storm restoration costs that were expensed. Restoration costs associated with multiple storms since 2018 that impacted FPL's customers in the former Gulf Power Company service area are being collected from FPL's northwest Florida customers through a storm damage surcharge through late 2024 and are recorded as regulatory assets. As of December 31, 2022, the balance was $155 million, of which $101 million and $54 million are included in current regulatory assets and noncurrent regulatory assets, respectively, on NEE's and FPL's consolidated balance sheets. As of December 31, 2021, the balance was $242 million, of which $92 million and $150 million are
Impairment of Long-Lived Assets	Impairment of Long-Lived Assets – NEE evaluates long-lived assets for impairment when events or changes in circumstances indicate that the carrying amount may not be recoverable. The impairment loss to be recognized is the amount by which the carrying value of the long-lived asset exceeds the asset's fair value. In most instances, the fair value is determined by discounting estimated future cash flows using an appropriate interest rate.
Impairment of Equity Method Investments	Impairment of Equity Method Investments – NEE evaluates its equity method investments for impairment when events or changes in circumstances indicate that the fair value of the investment is less than the carrying value and the investment may be other-than-temporarily impaired. An impairment loss is required to be recognized if the impairment is deemed to be other than temporary. Investments that are other-than-temporarily impaired are written down to their estimated fair value and cannot subsequently be written back up for increases in estimated fair value. Impairment losses are recorded in equity in earnings (losses) of equity method investees in NEE’s consolidated statements of income. See Note 4 – Nonrecurring Fair Value Measurements.
Goodwill and Other Intangible Assets	NEE's, including FPL's, goodwill relates to various acquisitions which were accounted for using the acquisition method of accounting. Other intangible assets are primarily included in noncurrent other assets on NEE's consolidated balance sheets. NEE's other intangible assets subject to amortization are amortized, primarily on a straight-line basis, over their estimated useful lives. Amortization expense was approximately $18 million, $25 million and $27 million for the years ended December 31, 2022, 2021 and 2020, respectively, and is expected to be approximately $20 million, $22 million, $20 million, $22 million and $20 million for 2023, 2024, 2025, 2026 and 2027, respectively. Goodwill and other intangible assets not subject to amortization are assessed for impairment at least annually by applying a fair value-based analysis. Other intangible assets subject to amortization are periodically reviewed when impairment indicators are present to assess recoverability from future operations using undiscounted future cash flows.
Pension Plan	Pension Plan – NEE records the service cost component of net periodic benefit income to O&M expense and the non-service cost component to other net periodic benefit income in NEE's consolidated statements of income. NEE allocates net periodic pension income to its subsidiaries based on the pensionable earnings of the subsidiaries' employees. Accounting guidance requires recognition of the funded status of the pension plan in the balance sheet, with changes in the funded status recognized in other comprehensive income within shareholders' equity in the year in which the changes occur. Since NEE is the plan sponsor, and its subsidiaries do not have separate rights to the plan assets or direct obligations to their employees, this accounting guidance is reflected at NEE and not allocated to the subsidiaries. The portion of previously unrecognized actuarial gains and losses and prior service costs or credits that are estimated to be allocable to FPL as net periodic (income) cost in future periods and that otherwise would be recorded in accumulated other comprehensive income (AOCI) are classified as regulatory assets and liabilities at NEE in accordance with regulatory treatment.
Stock-Based Compensation	Stock-Based Compensation – NEE accounts for stock-based payment transactions based on grant-date fair value. Compensation costs for awards with graded vesting are recognized on a straight-line basis over the requisite service period for the entire award. Forfeitures of stock-based awards are recognized as they occur. See Note 14 – Stock-Based Compensation.
Retirement of Long-Term Debt	Retirement of Long-Term Debt – For NEE's rate-regulated subsidiaries, including FPL, gains and losses that result from differences in reacquisition cost and the net book value of long-term debt which is retired are deferred as a regulatory asset or liability and amortized to interest expense ratably over the remaining life of the original issue, which is consistent with their treatment in the ratemaking process. NEE's non-rate regulated subsidiaries recognize such differences in interest expense at the time of retirement.
Reference Rate Reform	Reference Rate Reform – In March 2020, the Financial Accounting Standards Board issued an accounting standards update which provides certain options to apply accounting guidance on contract modifications and hedge accounting as companies transition from the London Inter-Bank Offered Rate (LIBOR) and other interbank offered rates to alternative reference rates. NEE’s and FPL’s contracts that reference LIBOR or other interbank offered rates mainly relate to debt and derivative instruments. The standards update was effective upon issuance but can be applied prospectively through December 31, 2024. During the fourth quarter of 2021, NEE began utilizing options provided by the standards update with regard to modifications to debt and debt-related hedging instruments. NEE will continue to evaluate reference rate modifications to debt and derivative instruments through December 31, 2024 and continue to apply the standards update if eligible. Although the full impact is unknown, to date there has not been a material impact to NEE or FPL.
Income Taxes	Income Taxes – Deferred income taxes are recognized on all significant temporary differences between the financial statement and tax bases of assets and liabilities, and are presented as noncurrent on NEE's and FPL's consolidated balance sheets. In connection with the tax sharing agreement between NEE and certain of its subsidiaries, the income tax provision at each applicable subsidiary reflects the use of the "separate return method," except that tax benefits that could not be used on a separate return basis, but are used on the consolidated tax return, are recorded by the applicable subsidiary that generated the tax benefits. Any remaining consolidated income tax benefits or expenses are recorded at the corporate level. Included in other regulatory assets and other regulatory liabilities on NEE's and FPL's consolidated balance sheets is the revenue equivalent of the difference in deferred income taxes computed under accounting rules, as compared to regulatory accounting rules. The net regulatory liability totaled $3,504 million ($3,449 million for FPL) and $3,780 million ($3,723 million for FPL) at December 31, 2022 and 2021, respectively, and is being amortized in accordance with the regulatory treatment over the estimated lives of the assets or liabilities for which the deferred tax amount was initially recognized. Production tax credits (PTCs) are recognized as wind and solar energy is generated and sold based on a per kWh rate prescribed in applicable federal and state statutes and are recorded as a reduction of current income taxes payable, unless limited by tax law in which instance they are recorded as deferred tax assets. NEER recognizes ITCs as a reduction to income tax expense when the related energy property is placed into service. FPL recognizes ITCs as a reduction to income tax expense over the depreciable life of the related energy property. At December 31, 2022 and 2021, FPL’s accumulated deferred ITCs were approximately $1,031 million and $1,054 million, respectively, and are included in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. A valuation allowance is recorded to reduce the carrying amounts of deferred tax assets when it is more likely than not that such assets will not be realized. NEE recognizes interest income (expense) related to unrecognized tax benefits (liabilities) in interest income and interest expense, respectively, net of the amount deferred at FPL. At FPL, the offset to accrued interest receivable (payable) on income taxes is classified as a regulatory liability (regulatory asset) which will be amortized to income (expense) over a five-year period upon settlement in accordance with regulatory treatment. All tax positions taken by NEE in its income tax returns that are recognized in the financial statements must satisfy a more-likely-than-not threshold. NEE and its subsidiaries file income tax returns in the U.S. federal jurisdiction and various states, the most significant of which is Florida, and certain foreign jurisdictions. Federal tax liabilities, with the exception of certain refund claims, are effectively settled for all years prior to 2017. State and foreign tax liabilities, which have varied statutes of limitations regarding additional assessments, are generally effectively settled for years prior to 2017. At December 31, 2022, NEE had unrecognized tax benefits of approximately $119 million that, if recognized, could impact the annual effective income tax rate. The amounts of unrecognized tax benefits and related interest accruals may change within the next 12 months; however, NEE and FPL do not expect these changes to have a significant impact on NEE’s or FPL’s financial statements. See Note 5.
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 generation, solar generation and battery storage facilities, with generating/storage capacity in operation or under construction totaling approximately 12,413 MW, 2,360 MW and 714 MW, respectively, at December 31, 2022 , to third-party investors. NEE retains a controlling interest in the entities and therefore presents the Class B member interests as noncontrolling interests. Noncontrolling interests represents the portion of net assets in consolidated entities that are not owned by NEE and are reported as a component of equity in NEE’s consolidated balance sheet. The third-party investors are allocated earnings, tax attributes and cash flows in accordance with the respective limited liability company agreements. Those economics are allocated primarily to the third-party investors until they receive a targeted
Redeemable Noncontrolling Interests	Redeemable Noncontrolling Interests – Certain subsidiaries of NextEra Energy Resources sold Class B membership interests in entities that have ownership interests in wind generation, as well as solar and solar plus battery storage facilities to third-party investors. As specified in the respective limited liability company agreements, if, subject to certain contingencies, certain events occur, including, among others, those that would delay completion or cancel any of the underlying projects, an investor has the option to require NEER to return all or part of its investment. As these potential redemptions were outside of NEER’s control, these balances were classified as redeemable noncontrolling interests on NEE's consolidated balance sheets as of December 31, 2022 and 2021. During 2022, the contingencies associated with the December 31, 2021 balance were resolved and reclassified to noncontrolling interests. The contingencies associated with the December 31, 2022 balance are expected to be resolved in 2023.
Variable Interest Entities (VIEs)	Variable Interest Entities (VIEs) – An entity is considered to be a VIE when its total equity investment at risk is not sufficient to permit the entity to finance its activities without additional subordinated financial support, or its equity investors, as a group, lack the characteristics of having a controlling financial interest. A reporting company is required to consolidate a VIE as its primary beneficiary when it has both the power to direct the activities of the VIE that most significantly impact the VIE's economic performance, and the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. NEE and FPL evaluate whether an entity is a VIE whenever reconsideration events as defined by the accounting guidance occur. See Note 9.
Leases	Leases – NEE and FPL determine if an arrangement is a lease at inception. NEE and FPL recognize a right-of-use (ROU) asset and a lease liability for operating and finance leases by recognizing and measuring leases at the commencement date based on the present value of lease payments over the lease term. For sales-type leases, the book value of the leased asset is removed from the balance sheet and a net investment in sales-type lease is recognized based on fixed payments under the contract and the residual value of the asset being leased. NEE and FPL have elected not to apply the recognition requirements to short-term leases and not to separate nonlease components from associated lease components for all classes of underlying assets except for purchased power agreements. ROU assets are includ ed in
Disposal of a Business/Assets and Sale of Noncontrolling Ownership Interests	Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests – In December 2022, subsidiaries of NextEra Energy Resources sold (i) a 49% controlling ownership interest in three wind generation facilities and one solar plus battery facility located in geographically diverse locations throughout the U.S. with a total generating capacity of 1,437 MW and 65 MW of battery storage capacity, two of which facilities are currently under construction with expected in service dates in 2023, and (ii) their 100% ownership interest in three wind generation facilities located in the Midwest region of the U.S. with a total generating capacity of 347 MW to a NEP subsidiary for cash proceeds of approximately $805 million, plus working capital and other adjustments of $8 million (subject to post-closing adjustments). NEER will continue to consolidate the projects currently under construction for accounting purposes. A NextEra Energy Resources affiliate will continue to operate the facilities included in the sale. In connection with the sale, a gain of approximately $301 million ($230 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2022 and is included in the gains on disposal of businesses/assets – net. In connection with the facilities currently under construction, approximately $251 million of cash received was recorded as contract liabilities, which is included in current other liabilities on NEE's consolidated balance sheet at December 31, 2022. The contract liabilities relate to sale proceeds from NEP of approximately $150 million and differential membership interests of approximately $101 million. The contract liabilities associated with the sale proceeds and the differential membership interests are subject to the two facilities under construction achieving commercial operations by specified dates in 2023. The contract liabilities will be reversed and the sale recognized for accounting purposes if the contingencies are resolved in 2023. Otherwise, NextEra Energy Resources may be required to return proceeds related to differential membership interests and/or repurchase the facilities for up to $251 million. In addition, NextEra Energy Resources is responsible to pay for all construction costs related to the portfolio. At December 31, 2022, approximately $810 million is included in accounts payable on NEE's consolidated balance sheet and represents amounts owed by NextEra Energy Resources to NEP to reimburse NEP for construction costs. In September 2022, subsidiaries of NextEra Energy Resources completed the sale to a NEP subsidiary of a 67% controlling ownership interest in a battery storage facility in California with storage capacity of 230 MW, for cash proceeds of approximately $191 million, plus working capital and other adjustments of $2 million. A NextEra Energy Resources affiliate will continue to operate the facility included in the sale. In connection with the sale, a gain of approximately $87 million ($66 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2022 and is included in gains on disposal of businesses/assets – net. In December 2021, subsidiaries of NextEra Energy Resources sold their 100% ownership interest, comprised of a 50% controlling ownership interest to a NEP subsidiary and a 50% noncontrolling ownership interest to a third party, in a portfolio of seven wind generation facilities and six solar generation facilities in geographically diverse locations throughout the U.S. representing a total generating capacity of 2,520 MW and 115 MW of battery storage capacity, three of which facilities were under construction. Total cash proceeds for these two separate transactions totaled approximately $1.7 billion. NEER continued to consolidate the three projects under construction for accounting purposes through the first quarter of 2022. A NextEra Energy Resources affiliate will continue to operate the facilities included in the sales. In connection with the sales, a loss of approximately $53 million ($33 million after tax) was recorded in NEE’s consolidated statements of income for the year ended December 31, 2021 and is included in gains on disposal of businesses/assets – net. In connection with the three facilities that were under construction, approximately $668 million of cash received was recorded as contract liabilities, which is included in current other liabilities on NEE’s consolidated balance sheet at December 31, 2021. The contract liabilities related to sale proceeds from NEP and the third party of approximately $349 million and differential membership interests of approximately $319 million, of which $117 million was contingent on the enactment of a solar PTC by a specified date in 2022. In 2022, the three facilities achieved commercial operations and approximately $551 million of contract liabilities were reversed and the sale of those facilities was recognized for accounting purposes. In addition, the IRA was enacted establishing a solar PTC (see Note 5) which resolved the outstanding contingencies and $117 million of contract liabilities were reversed and a gain was recorded in NEE's consolidated statements of income for the year ended December 31, 2022 which is included in gains on disposal of businesses/assets – net. In addition, NextEra Energy Resources was responsible to pay for all construction costs related to the portfolio. At December 31, 2021, approximately $970 million was included in accounts payable on NEE's consolidated balance sheet and represented amounts owed by NextEra Energy Resources to NEP to reimburse NEP for construction costs. In 2021, subsidiaries of NextEra Energy Resources completed the sale to a NEP subsidiary of their 100% ownership interests in three wind generation facilities and one solar generation facility located in the West and Midwest regions of the U.S. with a total generating capacity of 467 MW and 33.3% of the noncontrolling ownership interests in four solar generation facilities and multiple distributed generation solar facilities located in geographically diverse locations throughout the U.S. representing a total net ownership interest in plant capacity (net generating capacity) of 122 MW for cash proceeds of approximately $563 million, plus working capital and other adjustments of $22 million. A NextEra Energy Resources affiliate will continue to operate the facilities included in the sale. In connection with the sale, a gain of approximately $94 million ($69 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2021, which is included in gains on disposal of businesses/assets, and noncontrolling interests of approximately $125 million and additional paid-in capital of approximately $60 million ($43 million after tax) were recorded on NEE's consolidated balance sheet at December 31, 2021. In 2020, a subsidiary of NextEra Energy Resources sold a 90% noncontrolling ownership interest, comprised of a 50% ownership interest to a third party and a 40% ownership interest to a NEP subsidiary, in a portfolio of three wind generation facilities and four solar generation facilities in geographically diverse locations throughout the U.S. representing a total net generating capacity of 900 MW. In addition, a subsidiary of NextEra Energy Resources also sold its 100% ownership interest in a 100 MW solar generation facility and a 30 MW battery storage facility (solar-plus-storage facility) that was under construction in Arizona to a NEP subsidiary. Total cash proceeds for these two separate transactions totaled approximately $656 million. NEER continued to consolidate the projects until the sale was recognized for accounting purposes, see Note 9 – NEER. A NextEra Energy Resources affiliate will continue to operate the facilities included in the sale. I n connection with the 90% sale, noncontrolling interests of approximately $689 million and a reduction to additional paid-in capital of approximately $188 million ($165 million after tax) were recorded on NEE's consolidated balance sheet. In connection with the solar-plus-storage facility transaction, approximately $155 million of cash received was recorded as a contract liability, and upon the solar-plus-storage facility achieving commercial operations in 2021, the contract liability was reversed and the sale was recognized for accounting purposes.
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 (see Note 3) 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 2022, 2021 and 2020, NEE’s revenue from contracts with customers was approximately $23.0 billion ($17.2 billion at FPL), $18.8 billion ($14.1 billion at FPL) and $17.0 billion ($13.0 billion at FPL), respectively. NEE's and FPL's receivables are primarily associated with revenues earned from contracts with customers, as well as derivative and lease transactions at NEER, and consist of both billed and unbilled amounts, which are recorded in customer receivables and other receivables on NEE's and FPL's consolidated balance sheets. Receivables represent unconditional rights to consideration and reflect the differences in timing of revenue recognition and cash collections. For substantially all of NEE's and FPL's receivables, regardless of the type of revenue transaction from which the receivable originated, customer and counterparty credit risk is managed in the same manner and the terms and conditions of payment are similar. During 2021, NEER did not recognize approximately $180 million of revenue related to reimbursable expenses from a counterparty that were deemed not probable of collection. These reimbursable expenses arose from the impacts of the February 2021 weather event. These determinations were made based on assessments of the counterparty's creditworthiness and NEER's ability to collect. FPL – FPL’s revenues are derived primarily from tariff-based sales that result from providing electricity to retail customers in Florida with no defined contractual term. Electricity sales to retail customers account for approximately 90% of FPL’s 2022 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, 2022 and 2021, FPL's unbilled revenues amounted to approximately $661 million and $583 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, 2022, FPL expects to record approximately $390 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 2023 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 through 2036, certain power purchase agreements with maturity dates through
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 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 substantially all recognized in net cash provided by operating activities in NEE's and FPL's consolidated statements of cash flows.
Fair Value of Financial Instruments	Fair Value Measurements of Derivative Instruments – The fair value of assets and liabilities are determined using either unadjusted quoted prices in active markets (Level 1) or pricing inputs that are observable (Level 2) whenever that information is available and using unobservable inputs (Level 3) to estimate fair value only when relevant observable inputs are not available. NEE and FPL use several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those assets and liabilities that are measured at fair value on a recurring basis. NEE's and FPL's assessment of the significance of any particular input to the fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Non-performance risk, including the consideration of a credit valuation adjustment, is also considered in the determination of fair value for all assets and liabilities measured at fair value. NEE and FPL measure the fair value of commodity contracts using a combination of market and income approaches utilizing prices observed on commodities exchanges and in the OTC markets, or through the use of industry-standard valuation techniques, such as option modeling or discounted cash flows techniques, incorporating both observable and unobservable valuation inputs. The resulting measurements are the best estimate of fair value as represented by the transfer of the asset or liability through an orderly transaction in the marketplace at the measurement date. Most exchange-traded derivative assets and liabilities are valued directly using unadjusted quoted prices. For exchange-traded derivative assets and liabilities where the principal market is deemed to be inactive based on average daily volumes and open interest, the measurement is established using settlement prices from the exchanges, and therefore considered to be valued using other observable inputs. NEE, through its subsidiaries, including FPL, also enters into OTC commodity contract derivatives. The majority of these contracts are transacted at liquid trading points, and the prices for these contracts are verified using quoted prices in active markets from exchanges, brokers or pricing services for similar contracts. NEE, through NEER, also enters into full requirements contracts, which, in most cases, meet the definition of derivatives and are measured at fair value. These contracts typically have one or more inputs that are not observable and are significant to the valuation of the contract. In addition, certain exchange and non-exchange traded derivative options at NEE have one or more significant inputs that are not observable, and are valued using industry-standard option models. In all cases where NEE and FPL use significant unobservable inputs for the valuation of a commodity contract, consideration is given to the assumptions that market participants would use in valuing the asset or liability. The primary input to the valuation models for commodity contracts is the forward commodity curve for the respective instruments. Other inputs include, but are not limited to, assumptions about market liquidity, volatility, correlation and contract duration as more fully described below in Significant Unobservable Inputs Used in Recurring Fair Value Measurements. In instances where the reference markets are deemed to be inactive or do not have transactions for a similar contract, the derivative assets and liabilities may be valued using significant other observable inputs and potentially significant unobservable inputs. In such instances, the valuation for these contracts is established using techniques including extrapolation from or interpolation between actively traded contracts, or estimated basis adjustments from liquid trading points. NEE and FPL regularly evaluate and validate the inputs used to determine fair value by a number of methods, consisting of various market price verification procedures, including the use of pricing services and multiple broker quotes to support the market price of the various commodities. In all cases where there are assumptions and models used to generate inputs for valuing derivative assets and liabilities, the review and verification of the assumptions, models and changes to the models are undertaken by individuals that are independent of those responsible for estimating fair value. Cash Equivalents and Restricted Cash Equivalents – NEE and FPL hold investments in money market funds. The fair value of these funds is estimated using a market approach based on current observable market prices. Special Use Funds and Other Investments – NEE and FPL hold primarily debt and equity securities directly, as well as indirectly through commingled funds. Substantially all directly held equity securities are valued at their quoted market prices. For directly held debt securities, multiple prices and price types are obtained from pricing vendors whenever possible, which enables cross-provider validations. A primary price source is identified based on asset type, class or issue of each security. Commingled funds, which are similar to mutual funds, are maintained by banks or investment companies and hold certain investments in accordance with a stated set of objectives. The fair value of commingled funds is primarily derived from the quoted prices in active markets of the underlying securities. Because the fund shares are offered to a limited group of investors, they are not considered to be traded in an active market. Fair Value Measurement Alternative – NEE holds investments in equity securities without readily determinable fair values, which are initially recorded at cost, of approximately $485 million and $72 million at December 31, 2022 and 2021, respectively, and are included in noncurrent other assets on NEE's consolidated balance sheets. Adjustments to carrying values are recorded as a result of observable price changes in transactions for identical or similar investments of the same issuer.

Summary of Significant Accoun_3

Summary of Significant Accounting and Reporting Policies (Tables)	12 Months Ended
	Dec. 31, 2022
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, 2022 2021 2022 2021 (millions) Regulatory assets: Current: Early retirement of generation facilities and transmission assets (a) $ 145 $ 140 $ 145 $ 140 Acquisition of purchased power agreements (b) 141 141 141 141 Deferred clause and franchise expenses 919 (c) 698 919 (c) 698 Storm restoration costs 911 (d) 92 911 (d) 92 Other 49 54 39 40 Total $ 2,165 $ 1,125 $ 2,155 $ 1,111 Noncurrent: Early retirement of generation facilities and transmission assets (a) $ 2,026 $ 2,233 $ 2,026 $ 2,233 Acquisition of purchased power agreements (b) 191 332 191 332 Deferred clause expenses 1,227 (c) 17 1,227 (c) 17 Storm restoration costs 326 (d) 150 326 (d) 150 Accrued asset removal costs (e) 532 263 532 263 Other 1,690 1,583 1,182 1,348 Total $ 5,992 $ 4,578 $ 5,484 $ 4,343 Regulatory liabilities: Current: Deferred clause revenues $ 339 $ 274 $ 339 $ 274 Other 11 15 10 4 Total $ 350 $ 289 $ 349 $ 278 Noncurrent: Asset retirement obligation regulatory expense difference $ 3,323 $ 4,290 $ 3,323 $ 4,290 Accrued asset removal costs (e) 658 782 623 752 Deferred taxes 4,233 4,561 4,129 4,457 Other 1,412 1,640 1,383 1,554 Total $ 9,626 $ 11,273 $ 9,458 $ 11,053 ______________________ (a) The majority of these regulatory assets are being amortized over 20 years. (b) The majority of these regulatory assets are being amortized over approximately 9 years. (c) The majority of these regulatory assets are expected to be amortized over 21 months beginning April 2023. See below regarding the 2022 fuel under-recovery. (d) The majority of these regulatory assets are expected to be amortized over 12 months beginning April 2023. See Storm Funds, Storm Reserves and Storm Cost Recovery below.
Schedule of Regulatory Liabilities	NEE's and FPL's regulatory assets and liabilities are as follows: NEE FPL December 31, December 31, 2022 2021 2022 2021 (millions) Regulatory assets: Current: Early retirement of generation facilities and transmission assets (a) $ 145 $ 140 $ 145 $ 140 Acquisition of purchased power agreements (b) 141 141 141 141 Deferred clause and franchise expenses 919 (c) 698 919 (c) 698 Storm restoration costs 911 (d) 92 911 (d) 92 Other 49 54 39 40 Total $ 2,165 $ 1,125 $ 2,155 $ 1,111 Noncurrent: Early retirement of generation facilities and transmission assets (a) $ 2,026 $ 2,233 $ 2,026 $ 2,233 Acquisition of purchased power agreements (b) 191 332 191 332 Deferred clause expenses 1,227 (c) 17 1,227 (c) 17 Storm restoration costs 326 (d) 150 326 (d) 150 Accrued asset removal costs (e) 532 263 532 263 Other 1,690 1,583 1,182 1,348 Total $ 5,992 $ 4,578 $ 5,484 $ 4,343 Regulatory liabilities: Current: Deferred clause revenues $ 339 $ 274 $ 339 $ 274 Other 11 15 10 4 Total $ 350 $ 289 $ 349 $ 278 Noncurrent: Asset retirement obligation regulatory expense difference $ 3,323 $ 4,290 $ 3,323 $ 4,290 Accrued asset removal costs (e) 658 782 623 752 Deferred taxes 4,233 4,561 4,129 4,457 Other 1,412 1,640 1,383 1,554 Total $ 9,626 $ 11,273 $ 9,458 $ 11,053 ______________________ (a) The majority of these regulatory assets are being amortized over 20 years. (b) The majority of these regulatory assets are being amortized over approximately 9 years. (c) The majority of these regulatory assets are expected to be amortized over 21 months beginning April 2023. See below regarding the 2022 fuel under-recovery. (d) The majority of these regulatory assets are expected to be amortized over 12 months beginning April 2023. See Storm Funds, Storm Reserves and Storm Cost Recovery below.
Schedule of Goodwill and Other Intangible Assets	NEE's goodwill and other intangible assets are as follows: Weighted- December 31, 2022 2021 (years) (millions) Goodwill (by reporting unit): FPL segment, primarily rate-regulated utilities (see Note 6 – Merger of FPL and Gulf Power Company) $ 2,989 $ 2,989 NEER segment: Rate-regulated assets, primarily transmission (see Note 6 – GridLiance) 1,218 1,206 Gas infrastructure 487 487 Customer supply and trading 95 95 Clean energy assets 54 56 Corporate and Other 11 11 Total goodwill $ 4,854 $ 4,844 Other intangible assets not subject to amortization, primarily land easements $ 136 $ 136 Other intangible assets subject to amortization: Purchased power agreements 16 $ 549 $ 507 Other, primarily transportation contracts and customer lists 24 173 187 Total 722 694 Accumulated amortization (99) (88) Total other intangible assets subject to amortization – net $ 623 $ 606

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2022
Derivative [Line Items]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	Therefore, the tables below also present the derivative positions on a net basis, which reflect the offsetting of positions of certain transactions within the portfolio, the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral, as well as the location of the net derivative position on the consolidated balance sheets. December 31, 2022 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: NEE: Commodity contracts $ 5,372 $ 7,559 $ 2,094 $ (12,030) $ 2,995 Interest rate contracts $ — $ 583 $ — $ (49) 534 Foreign currency contracts $ — $ — $ — $ (4) (4) Total derivative assets $ 3,525 FPL – commodity contracts $ — $ 11 $ 25 $ (7) $ 29 Liabilities: NEE: Commodity contracts $ 7,185 $ 7,620 $ 2,948 $ (13,010) $ 4,743 Interest rate contracts $ — $ 191 $ — $ (49) 142 Foreign currency contracts $ — $ 130 $ — $ (4) 126 Total derivative liabilities $ 5,011 FPL – commodity contracts $ — $ 4 $ 16 $ (7) $ 13 Net fair value by NEE balance sheet line item: Current derivative assets (b) $ 1,590 Noncurrent derivative assets (c) 1,935 Total derivative assets $ 3,525 Current derivative liabilities (d) $ 2,102 Noncurrent derivative liabilities (e) 2,909 Total derivative liabilities $ 5,011 Net fair value by FPL balance sheet line item: Current other assets $ 19 Noncurrent other assets 10 Total derivative assets $ 29 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 $299 million in margin cash collateral received from counterparties. (c) Reflects the netting of approximately $262 million in margin cash collateral received from counterparties. (d) Reflects the netting of approximately $328 million in margin cash collateral paid to counterparties. (e) Reflects the netting of approximately $1,213 million in margin cash collateral paid to counterparties. December 31, 2021 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: NEE: Commodity contracts $ 1,896 $ 5,082 $ 1,401 $ (6,622) $ 1,757 Interest rate contracts $ — $ 106 $ — $ (30) 76 Foreign currency contracts $ — $ 8 $ — $ (17) (9) Total derivative assets $ 1,824 FPL – commodity contracts $ — $ 3 $ 13 $ (3) $ 13 Liabilities: NEE: Commodity contracts $ 2,571 $ 4,990 $ 1,231 $ (6,594) $ 2,198 Interest rate contracts $ — $ 739 $ — $ (30) 709 Foreign currency contracts $ — $ 86 $ — $ (17) 69 Total derivative liabilities $ 2,976 FPL – commodity contracts $ — $ 8 $ 5 $ (3) $ 10 Net fair value by NEE balance sheet line item: Current derivative assets (b) $ 689 Noncurrent derivative assets (c) 1,135 Total derivative assets $ 1,824 Current derivative liabilities (d) $ 1,263 Noncurrent derivative liabilities (e) 1,713 Total derivative liabilities $ 2,976 Net fair value by FPL balance sheet line item: Current other assets $ 13 Current other liabilities $ 9 Noncurrent other liabilities 1 Total derivative liabilities $ 10 ______________________ (a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the consolidated balance sheets and are recorded in customer receivables – net and accounts payable, respectively. (b) Reflects the netting of approximately $150 million in margin cash collateral received from counterparties. (c) Reflects the netting of approximately $56 million in margin cash collateral received from counterparties. (d) Reflects the netting of approximately $6 million in margin cash collateral paid to counterparties. (e) Reflects the netting of approximately $172 million in margin cash collateral paid to counterparties December 31, 2022 Level 1 Level 2 Level 3 Total (millions) Assets: Cash equivalents and restricted cash equivalents: (a) NEE – equity securities $ 961 $ — $ — $ 961 FPL – equity securities $ 36 $ — $ — $ 36 Special use funds: (b) NEE: Equity securities $ 2,062 $ 2,375 (c) $ — $ 4,437 U.S. Government and municipal bonds $ 641 $ 63 $ — $ 704 Corporate debt securities $ 6 $ 716 $ — $ 722 Asset-backed securities $ — $ 615 $ — $ 615 Other debt securities $ 1 $ 19 $ — $ 20 FPL: Equity securities $ 743 $ 2,162 (c) $ — $ 2,905 U.S. Government and municipal bonds $ 505 $ 29 $ — $ 534 Corporate debt securities $ 6 $ 547 $ — $ 553 Asset-backed securities $ — $ 473 $ — $ 473 Other debt securities $ 1 $ 11 $ — $ 12 Other investments: (d) NEE: Equity securities $ 30 $ 1 $ — $ 31 Debt securities $ 117 $ 300 $ 118 $ 535 FPL: Equity securities $ 9 $ — $ — $ 9 Debt securities $ — $ 114 $ — $ 114 ______________________ (a) Includes restricted cash equivalents of approximately $69 million ($33 million for FPL) in current other assets (b) Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below. (c) Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL. (d) Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets. December 31, 2021 Level 1 Level 2 Level 3 Total (millions) Assets: Cash equivalents and restricted cash equivalents: (a) NEE – equity securities $ 176 $ — $ — $ 176 FPL – equity securities $ 58 $ — $ — $ 58 Special use funds: (b) NEE: Equity securities $ 2,538 $ 2,973 (c) $ — $ 5,511 U.S. Government and municipal bonds $ 770 $ 75 $ — $ 845 Corporate debt securities $ 7 $ 955 $ — $ 962 Asset-backed securities $ — $ 663 $ — $ 663 Other debt securities $ 2 $ 33 $ — $ 35 FPL: Equity securities $ 862 $ 2,690 (c) $ — $ 3,552 U.S. Government and municipal bonds $ 624 $ 44 $ — $ 668 Corporate debt securities $ 6 $ 720 $ — $ 726 Asset-backed securities $ — $ 515 $ — $ 515 Other debt securities $ 2 $ 23 $ — $ 25 Other investments: (d) NEE: Equity securities $ 70 $ 2 $ — $ 72 Debt securities $ 111 $ 162 $ 12 $ 285 FPL – equity securities $ 13 $ — $ — $ 13 ______________________ (a) Includes restricted cash equivalents of approximately $56 million ($53 million for FPL) in current other assets (b) Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below. (c) Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL. (d) Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets.
Fair Value Inputs, Assets, Quantitative Information	The significant unobservable inputs used in the valuation of NEE's commodity contracts categorized as Level 3 of the fair value hierarchy at December 31, 2022 are as follows: Transaction Type Fair Value at Valuation Significant Range Weighted-average (a) Assets Liabilities (millions) Forward contracts – power $ 222 $ 621 Discounted cash flow Forward price (per MWh (b) ) $(9) — $564 $51 Forward contracts – gas 349 307 Discounted cash flow Forward price (per MMBtu (c) ) $2 — $23 $4 Forward contracts – congestion 68 12 Discounted cash flow Forward price (per MWh (b) ) $(21) — $26 $1 Options – power 114 5 Option models Implied correlations 44% — 90% 56% Implied volatilities 32% — 361% 134% Options – primarily gas 726 736 Option models Implied correlations 44% — 90% 56% Implied volatilities 24% — 298% 59% Full requirements and unit contingent contracts 457 1,037 Discounted cash flow Forward price (per MWh (b) ) $13 — $424 $73 Customer migration rate (d) —% — 103% 6% Forward contracts – other 158 230 Total $ 2,094 $ 2,948 ______________________ (a) Unobservable inputs were weighted by volume. (b) Megawatt-hours (c) One million British thermal units (d) Applies only to full requirements contracts.
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation	The sensitivity of NEE's fair value measurements to increases (decreases) in the significant unobservable inputs is as follows: Significant Unobservable Input Position Impact on Forward price Purchase power/gas Increase (decrease) Sell power/gas Decrease (increase) Implied correlations Purchase option Decrease (increase) Sell option Increase (decrease) Implied volatilities Purchase option Increase (decrease) Sell option Decrease (increase) Customer migration rate Sell power (a) Decrease (increase) ———————————— (a) Assumes the contract is in a gain position.
Reconciliation of changes in the fair value of derivatives measured based on significant unobservable inputs	The reconciliation of changes in the fair value of derivatives that are based on significant unobservable inputs is as follows: Years Ended December 31, 2022 2021 2020 NEE FPL NEE FPL NEE FPL (millions) Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year $ 170 $ 8 $ 1,374 $ (1) $ 1,207 $ (8) Realized and unrealized gains (losses): Included in earnings (a) (2,343) — (1,488) — 547 — Included in other comprehensive income (loss) (b) — — — — 1 — Included in regulatory assets and liabilities 158 158 8 8 2 2 Purchases 542 — 243 — 191 — Sales (c) — — — — 114 — Settlements 992 (157) 259 1 (562) 6 Issuances (362) — (196) — (123) — Transfers in (d) (4) — 2 — 18 (1) Transfers out (d) (7) — (32) — (21) — Fair value of net derivatives based on significant unobservable inputs at December 31 $ (854) $ 9 $ 170 $ 8 $ 1,374 $ (1) Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date (e) $ (1,162) $ — $ (924) $ — $ 317 $ — ______________________ (a) For the years ended December 31, 2022, 2021 and 2020, realized and unrealized gains (losses) of approximately $(2,343) million, $(1,488) million and $569 million are included in the consolidated statements of income in operating revenues and the balance is included in interest expense. (b) Included in net unrealized gains (losses) on foreign currency translation in the consolidated statements of comprehensive income. (c) See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests. (d) Transfers into Level 3 were a result of decreased observability of market data. Transfers from Level 3 to Level 2 were a result of increased observability of market data.
Derivative instruments, gain (loss) in statement of financial performance	Gains (losses) related to NEE's derivatives are recorded in NEE's consolidated statements of income as follows: Years Ended December 31, 2022 2021 2020 (millions) Commodity contracts (a) – operating revenues (including $2,346 unrealized losses, $2,235 unrealized losses and $163 unrealized losses, respectively) $ (3,297) $ (2,710) $ 352 Foreign currency contracts – interest expense (including $53 unrealized losses, $89 unrealized losses and $26 unrealized gains, respectively) (61) (89) 8 Interest rate contracts – interest expense (including $1,021 unrealized gains, $319 unrealized gains and $396 unrealized losses, respectively) 1,221 264 (421) Losses reclassified from AOCI: Interest rate contracts (b) (5) (7) (35) Foreign currency contracts – interest expense (3) (3) (3) Total $ (2,145) $ (2,545) $ (99) ______________________ (a) For the years ended December 31, 2022, 2021 and 2020, FPL recorded gains of approximately $211 million, $7 million and $6 million, respectively, related to commodity contracts as regulatory liabilities on its consolidated balance sheets. (b) For the year ended December 31, 2020, approximately $23 million was reclassified to gains on disposal of businesses/assets – net (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests); remaining balances were reclassified to interest expense on NEE's consolidated statements of income.
Net notional volumes	NEE and FPL had derivative commodity contracts for the following net notional volumes: December 31, 2022 December 31, 2021 Commodity Type NEE FPL NEE FPL (millions) Power (104) MWh — (103) MWh — Natural gas (1,307) MMBtu 258 MMBtu (1,290) MMBtu 91 MMBtu Oil (38) barrels — (33) barrels —

Non-Derivative Fair Value Mea_2

Non-Derivative Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2022
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, 2022 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: NEE: Commodity contracts $ 5,372 $ 7,559 $ 2,094 $ (12,030) $ 2,995 Interest rate contracts $ — $ 583 $ — $ (49) 534 Foreign currency contracts $ — $ — $ — $ (4) (4) Total derivative assets $ 3,525 FPL – commodity contracts $ — $ 11 $ 25 $ (7) $ 29 Liabilities: NEE: Commodity contracts $ 7,185 $ 7,620 $ 2,948 $ (13,010) $ 4,743 Interest rate contracts $ — $ 191 $ — $ (49) 142 Foreign currency contracts $ — $ 130 $ — $ (4) 126 Total derivative liabilities $ 5,011 FPL – commodity contracts $ — $ 4 $ 16 $ (7) $ 13 Net fair value by NEE balance sheet line item: Current derivative assets (b) $ 1,590 Noncurrent derivative assets (c) 1,935 Total derivative assets $ 3,525 Current derivative liabilities (d) $ 2,102 Noncurrent derivative liabilities (e) 2,909 Total derivative liabilities $ 5,011 Net fair value by FPL balance sheet line item: Current other assets $ 19 Noncurrent other assets 10 Total derivative assets $ 29 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 $299 million in margin cash collateral received from counterparties. (c) Reflects the netting of approximately $262 million in margin cash collateral received from counterparties. (d) Reflects the netting of approximately $328 million in margin cash collateral paid to counterparties. (e) Reflects the netting of approximately $1,213 million in margin cash collateral paid to counterparties. December 31, 2021 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: NEE: Commodity contracts $ 1,896 $ 5,082 $ 1,401 $ (6,622) $ 1,757 Interest rate contracts $ — $ 106 $ — $ (30) 76 Foreign currency contracts $ — $ 8 $ — $ (17) (9) Total derivative assets $ 1,824 FPL – commodity contracts $ — $ 3 $ 13 $ (3) $ 13 Liabilities: NEE: Commodity contracts $ 2,571 $ 4,990 $ 1,231 $ (6,594) $ 2,198 Interest rate contracts $ — $ 739 $ — $ (30) 709 Foreign currency contracts $ — $ 86 $ — $ (17) 69 Total derivative liabilities $ 2,976 FPL – commodity contracts $ — $ 8 $ 5 $ (3) $ 10 Net fair value by NEE balance sheet line item: Current derivative assets (b) $ 689 Noncurrent derivative assets (c) 1,135 Total derivative assets $ 1,824 Current derivative liabilities (d) $ 1,263 Noncurrent derivative liabilities (e) 1,713 Total derivative liabilities $ 2,976 Net fair value by FPL balance sheet line item: Current other assets $ 13 Current other liabilities $ 9 Noncurrent other liabilities 1 Total derivative liabilities $ 10 ______________________ (a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the consolidated balance sheets and are recorded in customer receivables – net and accounts payable, respectively. (b) Reflects the netting of approximately $150 million in margin cash collateral received from counterparties. (c) Reflects the netting of approximately $56 million in margin cash collateral received from counterparties. (d) Reflects the netting of approximately $6 million in margin cash collateral paid to counterparties. (e) Reflects the netting of approximately $172 million in margin cash collateral paid to counterparties December 31, 2022 Level 1 Level 2 Level 3 Total (millions) Assets: Cash equivalents and restricted cash equivalents: (a) NEE – equity securities $ 961 $ — $ — $ 961 FPL – equity securities $ 36 $ — $ — $ 36 Special use funds: (b) NEE: Equity securities $ 2,062 $ 2,375 (c) $ — $ 4,437 U.S. Government and municipal bonds $ 641 $ 63 $ — $ 704 Corporate debt securities $ 6 $ 716 $ — $ 722 Asset-backed securities $ — $ 615 $ — $ 615 Other debt securities $ 1 $ 19 $ — $ 20 FPL: Equity securities $ 743 $ 2,162 (c) $ — $ 2,905 U.S. Government and municipal bonds $ 505 $ 29 $ — $ 534 Corporate debt securities $ 6 $ 547 $ — $ 553 Asset-backed securities $ — $ 473 $ — $ 473 Other debt securities $ 1 $ 11 $ — $ 12 Other investments: (d) NEE: Equity securities $ 30 $ 1 $ — $ 31 Debt securities $ 117 $ 300 $ 118 $ 535 FPL: Equity securities $ 9 $ — $ — $ 9 Debt securities $ — $ 114 $ — $ 114 ______________________ (a) Includes restricted cash equivalents of approximately $69 million ($33 million for FPL) in current other assets (b) Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below. (c) Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL. (d) Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets. December 31, 2021 Level 1 Level 2 Level 3 Total (millions) Assets: Cash equivalents and restricted cash equivalents: (a) NEE – equity securities $ 176 $ — $ — $ 176 FPL – equity securities $ 58 $ — $ — $ 58 Special use funds: (b) NEE: Equity securities $ 2,538 $ 2,973 (c) $ — $ 5,511 U.S. Government and municipal bonds $ 770 $ 75 $ — $ 845 Corporate debt securities $ 7 $ 955 $ — $ 962 Asset-backed securities $ — $ 663 $ — $ 663 Other debt securities $ 2 $ 33 $ — $ 35 FPL: Equity securities $ 862 $ 2,690 (c) $ — $ 3,552 U.S. Government and municipal bonds $ 624 $ 44 $ — $ 668 Corporate debt securities $ 6 $ 720 $ — $ 726 Asset-backed securities $ — $ 515 $ — $ 515 Other debt securities $ 2 $ 23 $ — $ 25 Other investments: (d) NEE: Equity securities $ 70 $ 2 $ — $ 72 Debt securities $ 111 $ 162 $ 12 $ 285 FPL – equity securities $ 13 $ — $ — $ 13 ______________________ (a) Includes restricted cash equivalents of approximately $56 million ($53 million for FPL) in current other assets (b) Excludes investments accounted for under the equity method and loans not measured at fair value on a recurring basis. See Fair Value of Financial Instruments Recorded at Other than Fair Value below. (c) Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL. (d) Included in noncurrent other assets on NEE's and FPL's consolidated balance sheets.
Fair Value, by Balance Sheet Grouping	The carrying amounts of commercial paper and other short-term debt approximate their fair values. The carrying amounts and estimated fair values of other financial instruments recorded at other than fair value are as follows: December 31, 2022 December 31, 2021 Carrying Estimated Carrying Estimated (millions) NEE: Special use funds (a) $ 998 $ 999 $ 906 $ 907 Other receivables, net of allowances (b) $ 221 $ 221 $ 26 $ 26 Long-term debt, including current portion $ 61,889 $ 57,892 (c) $ 52,745 $ 57,290 (c) FPL: Special use funds (a) $ 744 $ 744 $ 672 $ 672 Long-term debt, including current portion $ 21,002 $ 19,364 (c) $ 18,510 $ 21,379 (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 (primarily Level 3). (c) At December 31, 2022 and 2021, substantially all is Level 2 for NEE and FPL.
Unrealized Gains (Losses) Recognized On Equity Securities	Unrealized gains (losses) recognized on equity securities held at December 31, 2022, 2021 and 2020 are as follows: NEE FPL Years Ended December 31, Years Ended December 31, 2022 2021 2020 2022 2021 2020 (millions) Unrealized gains (losses) $ (1,028) $ 981 $ 627 $ (677) $ 652 $ 444
Debt Securities, Available-for-sale	Realized gains and losses and proceeds from the sale or maturity of available for sale debt securities are as follows: NEE FPL Years Ended December 31, Years Ended December 31, 2022 2021 2020 2022 2021 2020 (millions) Realized gains $ 30 $ 78 $ 110 $ 24 $ 59 $ 83 Realized losses $ 141 $ 73 $ 70 $ 111 $ 57 $ 56 Proceeds from sale or maturity of securities $ 2,207 $ 1,831 $ 2,541 $ 1,371 $ 1,330 $ 2,162 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, 2022 2021 2022 2021 (millions) Unrealized gains $ 4 $ 76 $ 3 $ 63 Unrealized losses (a) $ 285 $ 19 $ 193 $ 15 Fair value $ 2,315 $ 1,100 $ 1,466 $ 857 ______________________ (a) Unrealized losses on available for sale debt securities in an unrealized loss position for greater than twelve months at December 31, 2022 and 2021 were not material to NEE or FPL.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2022
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, 2022 2021 2020 2022 2021 2020 (millions) Federal: Current $ 11 $ (26) $ 105 $ 3 $ 85 $ 16 Deferred 497 311 (148) 684 545 474 Total federal 508 285 (43) 687 630 490 State: Current 41 (62) 18 2 1 32 Deferred 37 125 69 258 207 156 Total state 78 63 87 260 208 188 Total income taxes $ 586 $ 348 $ 44 $ 947 $ 838 $ 678
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, 2022 2021 2020 2022 2021 2020 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 1.6 1.6 2.8 4.4 4.1 4.2 Taxes attributable to noncontrolling interests 4.9 5.0 4.8 — — — PTCs and ITCs (6.8) (11.3) (12.7) (1.1) (0.7) (0.6) Amortization of deferred regulatory credit (4.8) (4.4) (7.2) (4.0) (3.5) (4.9) Foreign operations (a) 0.1 0.2 (2.4) — — — Other – net (0.7) (1.1) (4.5) 0.1 (0.2) (0.7) Effective income tax rate 15.3 % 11.0 % 1.8 % 20.4 % 20.7 % 19.0 % _________________________ (a) The 2020 gain on sale of the Spain solar projects was not taxable for federal and state income tax purposes (see Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests).
Schedule of deferred income tax liabilities and assets	The income tax effects of temporary differences giving rise to consolidated deferred income tax liabilities and assets are as follows: NEE FPL December 31, December 31, 2022 2021 2022 2021 (millions) Deferred tax liabilities: Property-related $ 10,144 $ 10,018 $ 8,177 $ 7,831 Pension 552 564 439 425 Investments in partnerships and joint ventures 3,144 2,783 3 3 Other 2,666 2,092 1,914 1,232 Total deferred tax liabilities 16,506 15,457 10,533 9,491 Deferred tax assets and valuation allowance: Decommissioning reserves 306 296 306 296 Net operating loss carryforwards 346 330 19 2 Tax credit carryforwards 4,905 4,646 123 182 ARO and accrued asset removal costs 199 199 107 126 Regulatory liabilities 1,332 1,421 1,308 1,397 Other 822 733 295 351 Valuation allowance (a) (257) (282) — — Net deferred tax assets 7,653 7,343 2,158 2,354 Net deferred income taxes $ 8,853 $ 8,114 $ 8,375 $ 7,137 ______________________ (a) Reflects valuation allowances related to deferred state tax credits and state operating loss carryforwards. Deferred tax assets and liabilities are included on the consolidated balance sheets as follows: NEE FPL December 31, December 31, 2022 2021 2022 2021 (millions) Noncurrent other assets $ 219 $ 196 $ 1 $ — Deferred income taxes – noncurrent liabilities (9,072) (8,310) (8,376) (7,137) Net deferred income taxes $ (8,853) $ (8,114) $ (8,375) $ (7,137)
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, 2022 are as follows: Amount Expiration (millions) Net operating loss carryforwards: Federal $ 11 (a) 2033 – 2037 State 315 2022 – 2042 Foreign 20 (b) 2026 – 2042 Net operating loss carryforwards $ 346 Tax credit carryforwards: Federal $ 4,555 2028 – 2042 State 345 (c) 2023 – 2039 Foreign 5 2034 – 2042 Tax credit carryforwards $ 4,905 ______________________ (a) Includes $9 million of net operating loss carryforwards with an indefinite expiration period. (b) Includes $1 million of net operating loss carryforwards with an indefinite expiration period. (c) 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, 2022
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment consists of the following at December 31: NEE FPL 2022 2021 2022 2021 (millions) Electric plant in service and other property $ 124,963 $ 112,500 $ 74,353 $ 67,771 Nuclear fuel 1,684 1,606 1,190 1,170 Construction work in progress 15,675 14,141 7,026 6,326 Property, plant and equipment, gross 142,322 128,247 82,569 75,267 Accumulated depreciation and amortization (31,263) (28,899) (17,876) (17,040) Property, plant and equipment – net $ 111,059 $ 99,348 $ 64,693 $ 58,227
Proportionate Ownership Interest In Jointly-Owned Facilities	NEE's and FPL's proportionate ownership interest in jointly-owned facilities is as follows: December 31, 2022 Ownership Gross Investment (a) Accumulated Depreciation (a) Construction (millions) FPL: St. Lucie Unit No. 2 85 % $ 2,276 $ 1,062 $ 163 Daniel Units Nos. 1 and 2 (b) 50 % $ 753 $ 285 $ 22 Scherer Unit No. 3 (c) 25 % $ 405 $ 169 $ 1 NEER: Seabrook 88.23 % $ 1,355 $ 494 $ 74 Wyman Station Unit No. 4 91.19 % $ 31 $ 12 $ — Stanton 65 % $ 139 $ 25 $ — Transmission substation assets located in Seabrook, New Hampshire 88.23 % $ 140 $ 4 $ 4 ______________________ (a) Excludes nuclear fuel. (b) FPL intends to retire its share of these units in 2024. Net book value is reflected in other property on NEE's and FPL's consolidated balance sheets.

Equity Method Investments (Tabl

Equity Method Investments (Tables)	12 Months Ended
	Dec. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Summarized combined information for principal operating entities	Summarized combined information for these principal entities is as follows: 2022 2021 (millions) Operating revenue $ 1,705 $ 1,469 Operating income $ 1,423 $ 559 Net income $ 1,380 $ 739 Total assets $ 26,058 $ 29,537 Total liabilities $ 9,779 $ 9,501 Partners'/members' equity (a) $ 16,279 $ 20,036 NEE's share of underlying equity in the principal entities $ 2,379 $ 4,352 Difference between investment carrying amount and underlying equity in net assets (b) 2,589 1,133 NEE's investment carrying amount for the principal entities $ 4,968 $ 5,485 ______________________ (a) Reflects NEE's interest, as well as third-party interests, in NEP OpCo. (b) Approximately $2.5 billion in 2022 and $2.6 billion in 2021 is associated with NEP OpCo, of which approximately 75% relates to goodwill and is not being amortized and the remaining balance is being amortized primarily over a period of 13 to 25 years. The difference for 2021 is net of an approximately $1.5 billion impairment charge in 2020 related to NextEra Energy Resources' investment in Mountain Valley Pipeline. See Note 4 – Nonrecurring Fair Value Measurements for a discussion of impairment charges in 2020 and 2022.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2022
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, 2020 $ 3,166 $ 1,936 Liabilities incurred 79 7 Accretion expense 141 78 Liabilities settled (88) (a) (15) Revision in estimated cash flows – net (119) (b) 101 (c) Balances, December 31, 2021 3,179 (d) 2,107 (d) Liabilities incurred 82 — Accretion expense 145 81 Liabilities settled (80) (a) (22) Revision in estimated cash flows – net 2 10 Balances, December 31, 2022 $ 3,328 (d) $ 2,176 (d) ______________________ (a) Includes approximately $27 million and $35 million related to project sales to NEP as well as other sales of businesses and assets during the years ending December 31, 2022 and 2021, respectively. See Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests. (b) The increase at FPL discussed in (c) was offset primarily by the effect of revised cost estimates and useful lives of NEER's solar facilities. (c) Primarily reflects the effect of pending license extension requests of St. Lucie Units Nos. 1 and 2 for an additional 20 years. (d) Includes the current portion of AROs as of December 31, 2022 and 2021 of approximately $83 million ($68 million for FPL) and $97 million ($58 million for FPL), respectively, which are included in other current liabilities on NEE's and FPL's consolidated balance sheets.
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). 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, 2022 $ 7,495 $ 5,220 Balances, December 31, 2021 $ 8,846 $ 6,082

Employee Retirement Benefits (T

Employee Retirement Benefits (Tables)	12 Months Ended
	Dec. 31, 2022
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: 2022 2021 (millions) Change in pension plan assets: Fair value of plan assets at January 1 $ 5,688 $ 5,314 Actual return on plan assets (820) 627 Benefit payments (325) (253) Fair value of plan assets at December 31 $ 4,543 $ 5,688 Change in pension benefit obligation: Obligation at January 1 $ 3,445 $ 3,607 Service cost 86 90 Interest cost 77 64 Special termination benefit (a) 52 — Plan amendments 3 — Actuarial gains – net (627) (63) Benefit payments (325) (253) Obligation at December 31 (b) $ 2,711 $ 3,445 Funded status: Prepaid pension benefit costs at NEE at December 31 $ 1,832 $ 2,243 Prepaid pension benefit costs at FPL at December 31 (c) $ 1,732 $ 1,657 _________________________ (a) Reflects enhanced early retirement benefit. (b) NEE's accumulated pension benefit obligation, which includes no assumption about future salary levels, at December 31, 2022 and 2021 was approximately $2,650 million and $3,352 million, respectively. (c) Reflects FPL's allocated benefits under NEE's pension plan.
Unrecognized amounts included in accumulated other comprehensive income (loss)	NEE's unrecognized amounts included in accumulated other comprehensive income (loss) yet to be recognized as components of prepaid pension benefit costs are as follows: 2022 2021 (millions) Unrecognized prior service benefit (net of $0 tax expense and $1 tax expense, respectively) $ 1 $ 2 Unrecognized gains (losses) (net of $33 tax benefit and $7 tax expense, respectively) (91) 41 Total $ (90) $ 43
Unrecognized amounts included in regulatory assets (liabilities)	NEE's unrecognized amounts included in regulatory assets (liabilities) yet to be recognized as components of net prepaid pension benefit costs are as follows: 2022 2021 (millions) Unrecognized prior service cost (benefit) $ 2 $ (1) Unrecognized losses (gains) 277 (80) Total $ 279 $ (81)
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. 2022 2021 Discount rate 5.05 % 2.87 % Salary increase 4.90 % 4.90 % Weighted-average interest crediting rate 3.82 % 3.79 % The assumptions used to determine net periodic pension income for the pension plan are as follows: 2022 2021 2020 Discount rate 2.87 % 2.53 % 3.22 % Salary increase 4.90 % 4.40 % 4.40 % Expected long-term rate of return, net of investment management fees 7.35 % 7.35 % 7.35 % Weighted-average interest crediting rate 3.79 % 3.82 % 3.83 %
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, 2022 (a) Quoted Prices Significant Significant Total (millions) Equity securities (b) $ 1,246 $ 5 $ 1 $ 1,252 Equity commingled vehicles (c) — 731 — 731 U.S. Government and municipal bonds 85 5 — 90 Corporate debt securities (d) — 272 — 272 Asset-backed securities (e) — 413 — 413 Debt security commingled vehicles — 130 — 130 Convertible securities (f) 50 367 — 417 Total investments in the fair value hierarchy $ 1,381 $ 1,923 $ 1 3,305 Total investments measured at net asset value (g) 1,238 Total fair value of plan assets $ 4,543 _____________________ (a) See Notes 3 and 4 for discussion of fair value measurement techniques and inputs. (b) Includes foreign investments of $526 million. (c) Includes foreign investments of $191 million. (d) Includes foreign investments of $83 million. (e) Includes foreign investments of $129 million. (f) Includes foreign investments of $30 million. (g) Includes foreign investments of $242 million. December 31, 2021 (a) Quoted Prices Significant Significant Total (millions) Equity securities (b) $ 1,977 $ 29 $ 2 $ 2,008 Equity commingled vehicles (c) — 889 — 889 U.S. Government and municipal bonds 131 6 — 137 Corporate debt securities (d) — 351 — 351 Asset-backed securities — 386 — 386 Debt security commingled vehicles (e) — 219 — 219 Convertible securities (f) 91 489 — 580 Total investments in the fair value hierarchy $ 2,199 $ 2,369 $ 2 4,570 Total investments measured at net asset value (g) 1,118 Total fair value of plan assets $ 5,688 ______________________ (a) See Notes 3 and 4 for discussion of fair value measurement techniques and inputs. (b) Includes foreign investments of $927 million. (c) Includes foreign investments of $169 million. (d) Includes foreign investments of $109 million. (e) Includes foreign investments of $5 million. (f) Includes foreign investments of $41 million. (g) Includes foreign investments of $220 million.
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): 2023 $ 198 2024 $ 199 2025 $ 201 2026 $ 204 2027 $ 203 2028 – 2032 $ 1,008
Net periodic benefit (income) cost	Net Periodic (Income) Cost – The components of net periodic (income) cost for the plans are as follows: Pension Benefits Postretirement Benefits 2022 2021 2020 2022 2021 2020 (millions) Service cost $ 86 $ 90 $ 85 $ 1 $ 2 $ 1 Interest cost 77 64 92 5 4 8 Expected return on plan assets (363) (339) (321) — — — Amortization of actuarial loss — 24 18 3 5 3 Amortization of prior service benefit (1) (1) (1) (4) (15) (16) Special termination benefit 52 — 16 — — — Benefit plan settlement 27 — — — — — Net periodic (income) cost at NEE $ (122) $ (162) $ (111) $ 5 $ (4) $ (4) Net periodic (income) cost allocated to FPL $ (76) $ (108) $ (84) $ 4 $ (4) $ (4)
Components of net periodic benefit income (cost) recognized in OCI	Other Comprehensive Income – The components of net periodic income (cost) recognized in OCI for the pension plan are as follows: 2022 2021 2020 (millions) Prior service cost (net of $0 tax benefit) $ (1) $ — $ — Net gains (losses) (net of $43 tax benefit, $29 tax expense and $13 tax expense, respectively) (139) 95 42 Amortization of unrecognized losses (net of $2 tax expense, $2 tax expense and $1 tax expense, respectively) 7 6 5 Total $ (133) $ 101 $ 47
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: 2022 2021 (millions) Prior service cost (benefit) $ 2 $ (1) Unrecognized losses (gains) 375 (226) Amortization of prior service benefit 1 — Amortization of unrecognized losses (18) (16) Total $ 360 $ (243)

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2022
Debt Disclosure [Abstract]
Debt Issuances and Borrowings by Subsidiaries	Long-term debt consists of the following: December 31, 2022 2021 Maturity Balance Weighted- Balance Weighted- (millions) (millions) FPL: First mortgage bonds – fixed 2023-2051 $ 15,790 4.03 % $ 14,290 4.20 % Pollution control, solid waste disposal and industrial development revenue bonds – primarily variable (a) 2023-2052 1,366 3.20 % 1,407 0.15 % Senior unsecured notes – primarily variable (b)(c) 2023-2072 4,042 3.99 % 2,697 1.37 % Other long-term debt – primarily variable (c) 2046 7 7.90 % 307 0.82 % Unamortized debt issuance costs and discount (203) (191) Total long-term debt of FPL 21,002 18,510 Less current portion of long-term debt 1,547 536 Long-term debt of FPL, excluding current portion 19,455 17,974 NEER: NextEra Energy Resources: Senior secured limited-recourse long-term debt – variable (c)(d) 2024-2037 3,582 6.24 % 3,100 1.74 % Senior secured limited-recourse long-term loans – fixed 2028-2052 2,452 3.43 % 2,475 3.30 % Other long-term debt – primarily variable (c)(d) 2026-2048 777 6.33 % 785 2.50 % NEET – long-term debt – primarily fixed (d) 2023-2052 2,348 5.10 % 1,151 2.69 % Unamortized debt issuance costs and premium (108) (92) Total long-term debt of NEER 9,051 7,419 Less current portion of long-term debt 694 664 Long-term debt of NEER, excluding current portion 8,357 6,755 NEECH: Debentures – fixed 2023-2062 17,865 2.99 % 10,990 2.21 % Debentures – variable (c) 2023-2024 2,200 4.14 % 3,850 0.56 % Debentures, related to NEE's equity units – fixed 2025-2027 6,500 2.28 % 6,000 1.46 % Junior subordinated debentures – primarily fixed (d) 2057-2082 3,723 5.23 % 3,723 4.54 % Japanese yen denominated long-term debt – primarily variable (c)(d)(e) 2023-2030 506 0.73 % 582 1.49 % Australian dollar denominated long-term debt – fixed (e) 2026 338 2.20 % 360 2.20 % Other long-term debt – fixed 2023 164 0.92 % 186 0.92 % Other long-term debt – variable (c) 2024 675 5.02 % 1,245 0.64 % Unamortized debt issuance costs, premium (135) (120) Total long-term debt of NEECH 31,836 26,816 Less current portion of long-term debt 4,392 585 Long-term debt of NEECH, excluding current portion 27,444 26,231 Total long-term debt $ 55,256 $ 50,960 ______________________ (a) Includes variable rate tax exempt bonds that permit individual bondholders to tender the bonds for purchase at any time prior to maturity. In the event these variable rate tax exempt bonds are tendered for purchase, they would be remarketed by a designated remarketing agent in accordance with the related indenture. If the remarketing is unsuccessful, FPL would be required to purchase these variable rate tax exempt bonds. At December 31, 2022, these variable rate tax exempt bonds totaled approximately $1,334 million. All variable rate tax exempt bonds tendered for purchase have been successfully remarketed. FPL's syndicated revolving credit facilities are available to support the purchase of the variable rate tax exempt bonds. Variable interest rate is established at various intervals by the remarketing agent. (b) At December 31, 2022, includes approximately $1,327 million of floating rate notes that permit individual noteholders to require repayment at specified dates prior to maturity. FPL’s syndicated revolving credit facilities are available to support the purchase of the floating rate notes. (c) Variable rate is based on an underlying index plus a specified margin. (d) Interest rate contracts, primarily swaps, have been entered into with respect to certain of these debt issuances. See Note 3. (e) Foreign currency contracts have been entered into with respect to these debt issuances. See Note 3.

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2022
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, 2022 2021 2020 (millions, except per share amounts) Numerator – net income attributable to NEE $ 4,147 $ 3,573 $ 2,919 Denominator: Weighted-average number of common shares outstanding – basic 1,972.6 1,962.5 1,959.0 Equity units, stock options, performance share awards and restricted stock (a) 6.0 9.7 9.8 Weighted-average number of common shares outstanding – assuming dilution 1,978.6 1,972.2 1,968.8 Earnings per share attributable to NEE: Basic $ 2.10 $ 1.82 $ 1.49 Assuming dilution $ 2.10 $ 1.81 $ 1.48 ______________________ (a) Calculated using the treasury stock method. Performance share awards are included in diluted weighted-average number of common shares outstanding based upon what would be issued if the end of the reporting period was the end of the term of the award.
Nonvested Awards Activity	The activity in restricted stock and performance share awards for the year ended December 31, 2022 was as follows: Shares/Units Weighted- Restricted Stock: Nonvested balance, January 1, 2022 1,817,732 $ 68.09 Granted 1,001,259 $ 75.13 Vested (758,006) $ 58.83 Forfeited (68,940) $ 76.65 Nonvested balance, December 31, 2022 1,992,045 $ 77.93 Performance Share Awards: Nonvested balance, January 1, 2022 1,412,149 $ 61.22 Granted 1,597,586 $ 58.67 Vested (1,563,850) $ 56.08 Forfeited (308,803) $ 74.01 Nonvested balance, December 31, 2022 1,137,082 $ 71.17
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: 2022 2021 2020 Expected volatility (a) 17.91 – 19.37% 17.32 – 17.75% 14.63 – 16.31% Expected dividends 2.32 – 2.50% 2.30 – 2.44% 2.50 – 2.72% Expected term (years) (b) 6.5 7.0 7.0 Risk-free rate 1.91 – 3.85% 0.80 – 1.27% 0.49 – 1.52% ______________________ (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, 2022 was as follows: Shares Weighted- Weighted- Aggregate Balance, January 1, 2022 10,013,312 $ 44.87 Granted 1,304,270 $ 75.28 Exercised (594,220) $ 23.77 Forfeited (23,952) $ 78.33 Balance, December 31, 2022 10,699,410 $ 49.67 5.7 $ 363 Exercisable, December 31, 2022 8,152,185 $ 41.28 4.8 $ 345
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, 2019 $ (27) $ 11 $ (114) $ (42) $ 3 $ (169) Other comprehensive income before reclassifications — 12 37 13 1 63 Amounts reclassified from AOCI 12 (a) (3) (b) 2 (c) — — 11 Net other comprehensive income 12 9 39 13 1 74 Less other comprehensive income attributable to noncontrolling interests — — — (7) — (7) Impact of disposal of a business 23 (d) — — (13) (d) — 10 Balances, December 31, 2020 8 20 (75) (49) 4 (92) Other comprehensive income (loss) before reclassifications — (11) 95 (1) 1 84 Amounts reclassified from AOCI 6 (a) (4) (b) 5 (c) — — 7 Net other comprehensive income (loss) 6 (15) 100 (1) 1 91 Less other comprehensive loss attributable to noncontrolling interests — — — 1 — 1 Balances, December 31, 2021 14 5 25 (49) 5 — Other comprehensive income (loss) before reclassifications — (84) (133) (44) 1 (260) Amounts reclassified from AOCI 6 (a) 10 (b) 7 (c) — — 23 Net other comprehensive income (loss) 6 (74) (126) (44) 1 (237) Less other comprehensive loss attributable to noncontrolling interests — — — 19 — 19 Balances, December 31, 2022 $ 20 $ (69) $ (101) $ (74) $ 6 $ (218) Attributable to noncontrolling interests $ — $ — $ — $ (14) $ — $ (14) ______________________ (a) Reclassified to interest expense in NEE's consolidated statements of income. See Note 3 – Income Statement Impact of Derivative Instruments. (b) Reclassified to gains on disposal of investments and other property – net in NEE's consolidated statements of income. (c) Reclassified to other net periodic benefit income in NEE's consolidated statements of income. (d) Reclassified to gains on disposal of businesses/assets – net and interest expense in NEE's consolidated statements of income. See Note 3 – Income Statement Impact of Derivative Instruments and Note 1 – Disposal of Businesses/Assets and Sale of Noncontrolling Ownership Interests.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Schedule of Planned Capital Expenditures	At December 31, 2022, estimated capital expenditures, on an accrual basis, for 2023 through 2027 were as follows: 2023 2024 2025 2026 2027 Total (millions) FPL: Generation: (a) New (b) $ 3,060 $ 2,315 $ 2,820 $ 3,670 $ 3,150 $ 15,015 Existing 1,615 1,175 1,045 1,280 1,465 6,580 Transmission and distribution (c) 3,545 3,975 3,645 3,340 3,575 18,080 Nuclear fuel 125 160 200 200 225 910 General and other 675 455 515 385 525 2,555 Total $ 9,020 $ 8,080 $ 8,225 $ 8,875 $ 8,940 $ 43,140 NEER: (d) Wind (e) $ 2,650 $ 1,095 $ 315 $ 20 $ 20 $ 4,100 Solar (f) 4,020 1,145 225 — — 5,390 Other clean energy (g) 1,175 350 55 75 45 1,700 Nuclear, including nuclear fuel 95 215 145 260 285 1,000 Rate-regulated transmission 170 65 45 10 10 300 Other 765 180 95 115 60 1,215 Total $ 8,875 $ 3,050 $ 880 $ 480 $ 420 $ 13,705 ______________________ (a) Includes AFUDC of approximately $105 million, $105 million, $90 million, $125 million and $115 million for 2023 through 2027, respectively. (b) Includes land, generation structures, transmission interconnection and integration and licensing. (c) Includes AFUDC of approximately $60 million, $50 million, $55 million, $30 million and $30 million for 2023 through 2027, respectively. (d) Represents capital expenditures for which applicable internal approvals and also, if required, regulatory approvals have been received. (e) Consists of capital expenditures for new wind projects and repowering of existing wind projects totaling approximately 2,955 MW, and related transmission. (f) Includes capital expenditures for new solar projects (including solar plus battery storage projects) totaling approximately 6,618 MW and related transmission.
Required Capacity and/or Minimum Payments	The required capacity and/or minimum payments under contracts, including those discussed above at December 31, 2022, were estimated as follows: 2023 2024 2025 2026 2027 Thereafter (millions) FPL (a) $ 1,040 $ 970 $ 940 $ 930 $ 850 $ 8,075 NEER (b)(c)(d) $ 2,995 $ 1,145 $ 135 $ 90 $ 80 $ 510 _______________________ (a) Includes approximately $410 million, $410 million, $405 million, $400 million, $400 million and $5,560 million in 2023 through 2027 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 $418 million, $419 million and $386 million for the years ended December 31, 2022, 2021 and 2020, respectively, of which $102 million, $105 million and $108 million, respectively, were eliminated in consolidation at NEE. (b) Excludes commitments related to equity contributions and a 20-year natural gas transportation agreement (approximately $70 million per year) with a joint venture, in which NEER has a 32.2% equity investment, that is constructing a natural gas pipeline. These commitments are subject to the completion of construction of the pipeline which has a very low probability of completion. See Note 4 – Nonrecurring Fair Value Measurements . (c) Includes approximately $260 million of commitments to invest in technology and other investments through 2031. See Note 9 – Other. (d) Includes approximately $205 million, $865 million, $5 million, $5 million, $0 million and $0 million for 2023 through 2027 and thereafter, respectively, of joint obligations of NEECH and NEER.

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2022
Segment Reporting [Abstract]
Segment Information	NEE's segment information is as follows: 2022 FPL NEER (a) Corp. and NEE (millions) Operating revenues $ 17,282 $ 3,720 $ (46) $ 20,956 Operating expenses – net $ 11,992 (b) $ 5,140 $ 265 $ 17,397 Gains (losses) on disposal of businesses/assets – net $ 4 $ 536 $ (18) $ 522 Interest expense $ 768 $ 128 $ (311) $ 585 Depreciation and amortization $ 2,695 $ 1,722 $ 86 $ 4,503 Equity in earnings of equity method investees $ — $ 202 $ 1 $ 203 Income tax expense (benefit) $ 947 (c) $ (391) (c) $ 30 $ 586 Net income (loss) $ 3,701 $ (616) $ 161 $ 3,246 Net loss attributable to noncontrolling interests $ — $ 901 $ — $ 901 Net income attributable to NEE $ 3,701 $ 285 $ 161 $ 4,147 Capital expenditures, independent power and other investments and nuclear fuel purchases $ 9,185 $ 9,645 $ 453 $ 19,283 Property, plant and equipment – net $ 64,693 $ 45,840 $ 526 $ 111,059 Total assets $ 86,559 $ 70,713 $ 1,663 $ 158,935 Investment in equity method investees $ — $ 6,572 $ 10 $ 6,582 _________________________ (a) Interest expense allocated from NEECH to NextEra Energy Resources' subsidiaries 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) FPL's income statement line for total operating expenses – net includes gains (losses) on disposal of businesses/assets – net. (c) Includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 – Income Taxes. 2021 FPL NEER (a) Corp. and NEE (millions) Operating revenues $ 14,102 $ 3,053 $ (86) $ 17,069 Operating expenses – net $ 9,587 (b) $ 4,434 $ 212 $ 14,233 Gains (losses) on disposal of businesses/assets – net $ 1 $ 78 $ (2) $ 77 Interest expense $ 615 $ 367 $ 288 $ 1,270 Depreciation and amortization $ 2,266 $ 1,576 $ 82 $ 3,924 Equity in earnings of equity method investees $ — $ 666 $ — $ 666 Income tax expense (benefit) $ 838 $ (395) (c) $ (95) $ 348 Net income (loss) $ 3,206 $ (147) $ (232) $ 2,827 Net loss attributable to noncontrolling interests $ — $ 746 $ — $ 746 Net income (loss) attributable to NEE $ 3,206 $ 599 $ (232) $ 3,573 Capital expenditures, independent power and other investments and nuclear fuel purchases $ 7,570 $ 8,363 $ 144 $ 16,077 Property, plant and equipment – net $ 58,227 $ 40,900 $ 221 $ 99,348 Total assets $ 78,067 $ 62,113 $ 732 $ 140,912 Investment in equity method investees $ — $ 6,150 $ 9 $ 6,159 _________________________ (a) Interest expense allocated from NEECH to NextEra Energy Resources' subsidiaries 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) FPL's income statement line for total operating expenses – net includes gains (losses) on disposal of businesses/assets – net. (c) Includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 – Income Taxes. 2020 FPL NEER (a) Corp. and NEE (millions) Operating revenues $ 13,060 $ 5,046 $ (109) $ 17,997 Operating expenses – net $ 8,940 $ 4,125 $ 169 $ 13,234 Gains (losses) on disposal of businesses/assets – net $ — $ 363 $ (10) $ 353 Interest expense $ 641 $ 659 $ 650 $ 1,950 Depreciation and amortization $ 2,526 $ 1,460 $ 66 $ 4,052 Equity in losses of equity method investees $ — $ (1,351) $ — $ (1,351) Income tax expense (benefit) $ 678 $ (416) (b) $ (218) $ 44 Net income (loss) $ 2,890 $ (19) $ (502) $ 2,369 Net loss attributable to noncontrolling interests $ — $ 550 $ — $ 550 Net income (loss) attributable to NEE $ 2,890 $ 531 $ (502) $ 2,919 Capital expenditures, independent power and other investments and nuclear fuel purchases $ 7,679 $ 6,893 $ 38 $ 14,610 Property, plant and equipment – net $ 53,879 $ 37,842 $ 82 $ 91,803 Total assets $ 71,001 $ 55,633 $ 1,050 $ 127,684 Investment in equity method investees $ — $ 5,713 $ 15 $ 5,728 _________________________ (a) Interest expense allocated from NEECH to NextEra Energy Resources' subsidiaries 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) Includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 – Income Taxes.

Summary of Significant Accoun_4

Summary of Significant Accounting and Reporting Policies (Additional Information) (Details) € in Millions, account in Millions, $ in Millions			1 Months Ended				3 Months Ended	12 Months Ended
	Jan. 01, 2021	Dec. 31, 2020 USD ($) facility	Jan. 31, 2023 USD ($)	Dec. 31, 2022 USD ($) facility account county MW	Sep. 30, 2022 USD ($) MW	Dec. 31, 2021 USD ($) facility MW	Nov. 30, 2022 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($) facility account county unit MW	Dec. 31, 2021 USD ($) facility MW	Dec. 31, 2020 USD ($) facility MW	Aug. 31, 2022 USD ($)	Dec. 31, 2020 EUR (€) facility	Jan. 01, 2020 USD ($)
Regulated and Unregulated Operating Revenue [Abstract]
Revenue from contracts with customers									$ 23,000	$ 18,800	$ 17,000
Electric Plant, Depreciation and Amortization [Abstract]
Convertible ITCs									693	755
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Asset Retirement Obligation		$ 3,166		$ 3,328		$ 3,179			3,328	3,179	3,166
Restricted Cash [Abstract]
Restricted cash, current				1,840		677			1,840	677
Restricted cash related to margin cash collateral that is netted against derivative assets				7		121			7	121
Restricted cash related to margin cash collateral that is netted against derivative liabilities				1,541		172			1,541	172
Measurement of Credit Losses on Financial Instruments [Abstract]
Retained earnings				26,707		25,911			26,707	25,911
Accounts Receivable, Credit Loss Expense (Reversal)									(113)	(146)	(94)
Accounts Receivable, Allowance for Credit Loss, Noncurrent						127				127
Income Taxes [Abstract]
Revenue equivalent of the difference in accumulated deferred income taxes computed under accounting rules, as compared to regulatory accounting rules				3,504		3,780			$ 3,504	3,780
Amortization period									5 years
Unrecognized tax benefits that impact annual effective income tax rate				119					$ 119
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal									522	77	353
Customer deposits				560		485			560	485
Construction Costs				$ 1,760		1,378			$ 1,760	1,378
Storm Restoration Costs
Storm Funds Storm Reserves and Storm Cost Recovery Abstract
Regulatory asset, amortization period									12 months
St. Lucie Units Number One
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
License renewal period									20 years
St. Lucie Units Number Two
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
License renewal period									20 years
Accounting Standards Update 2016-13 [Member]
Measurement of Credit Losses on Financial Instruments [Abstract]
Retained earnings														$ 11
FPL [Member]
Basis of Presentation [Abstract]
Number of customer accounts (more than) | account				5.8					5.8
Number of counties In which entity operates | county				8					8
Regulated and Unregulated Operating Revenue [Abstract]
Revenue from contracts with customers									$ 17,200	14,100	13,000
Electric Plant, Depreciation and Amortization [Abstract]
Convertible ITCs									$ 111	116
Construction Activity [Abstract]
Threshold of plant in service balance at which AFUDC may be recorded (in hundredths)	0.40%	0.50%
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Maximum interval between nuclear decommissioning studies submitted to the FPSC for approval (in years)									5 years
For FPL, number of nuclear units | unit									4
FPL's portion of the ultimate costs of nuclear decommissioning				$ 9,600					$ 9,600
FPL's Ultimate costs of nuclear decommissioning, in current year dollars				2,500					2,500
FPL's fund earnings on decommissioning funds									58	173	132
Plant Dismantlement Approved Expense									26
Ultimate Costs Of Plant Dismantlement				2,400					2,400
Ultimate Costs Of Plant Dismantlement In Current Year Dollars				1,200					1,200
Asset Retirement Obligation		$ 1,936		2,176		2,107			2,176	2,107	1,936
Restricted Cash [Abstract]
Restricted cash, current				33		53			33	53
Measurement of Credit Losses on Financial Instruments [Abstract]
Retained earnings				13,986		12,285			13,986	12,285
Storm Funds Storm Reserves and Storm Cost Recovery Abstract
Recoverable Storm Restoration Costs							$ 1,300
Storm Reserve, Value												$ 220
Recoverable Storm Restoration Costs in Excess of Storm Reserve				1,100					1,100
Public Utilities, Accrued Storm Restoration Costs				(618)					(618)
Storm restoration costs										(28)	(183)
Storm restoration costs				(155)		242			(155)	242
Income Taxes [Abstract]
Revenue equivalent of the difference in accumulated deferred income taxes computed under accounting rules, as compared to regulatory accounting rules				3,449		3,723			3,449	3,723
Accumulated Deferred Investment Tax Credit				1,031		1,054			1,031	1,054
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Customer deposits				543		478			543	478
Construction Costs				559		601			$ 559	601
FPL [Member] | Subsequent Event
Fuel Recovery [Abstract]
Increase (Decrease) in under Energy Recovery			$ 2,100
Natural Gas Mid-Course Correction, Value			1,000
Storm Funds Storm Reserves and Storm Cost Recovery Abstract
Storm Reserve, Value			220
Storm Restoration Costs, Pre-2022			$ 136
FPL [Member] | St. Lucie Units Number Two
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
License renewal period									20 years
NEER [Member]
Construction Activity [Abstract]
Project development costs of NEER				$ 1,027		831			$ 1,027	831
Deemed capital structure of NEER (in hundredths)				70%					70%
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Asset Retirement Obligation				$ 1,200		1,100			$ 1,200	1,100
Ultimate Costs Of Nuclear Decommissioning For Wholly Owned Indirect Subsidiary				9,500					9,500
Ultimate Costs Of Nuclear Decommissioning In Current Year Dollars For Wholly Owned Indirect Subsidiary				2,000					2,000
Ultimate costs to dismantle wind and solar facilities									$ 2,500
Effective period for Seabrook's decommissioning funding plan (in years)									4 years
NEER [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Abstract]
Wind Electric Generating Facility Capability | MW									12,413
Solar generating facility capability | MW									2,360
Battery Storage Facility Capability [Line Items] | MW									714
Forecast [Member] | FPL [Member]
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Plant Dismantlement Approved Expense								$ 48
Regulatory Assets, Current | FPL [Member]
Storm Funds Storm Reserves and Storm Cost Recovery Abstract
Storm restoration costs				(101)		92			$ (101)	92
Regulatory Assets, Noncurrent | FPL [Member]
Storm Funds Storm Reserves and Storm Cost Recovery Abstract
Storm restoration costs				$ (54)		150			(54)	150
Franchise and Gross Receipts Taxes [Member]
Regulated and Unregulated Operating Revenue [Abstract]
Revenue from contracts with customers									1,035	852	800
Franchise and Gross Receipts Taxes [Member] | FPL [Member]
Regulated and Unregulated Operating Revenue [Abstract]
Revenue from contracts with customers									$ 1,035	$ 852	$ 800
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind facilities, one solar plus battery facility | Subsidiaries of NextEra Energy Resources | NEP [Member] | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold				49%					49%
Number Of Wind Generation Facilities | facility				3					3
Number of Solar Plus Battery Facilities | facility				1					1
Total generating facility capacity (mw) | MW				1,437
Battery storage facility capacity | MW				65
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind facilities | Subsidiaries of NextEra Energy Resources | NEP [Member] | United States, Midwest Region
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold				100%					100%
Number Of Wind Generation Facilities				3					3
Total generating facility capacity (mw) | MW				347
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and one solar plus battery facility and three wind facilities | NEER [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Including Discontinued Operation, Consideration				$ 805					$ 805
Disposal Group, Including Discontinued Operation, Working Capital				8					8
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal				301
Disposal Group, Not Discontinued Operation, Gain (Loss) On Disposal, Net Of Tax				230
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and one solar plus battery facility and three wind facilities | Subsidiaries of NextEra Energy Resources | NEP [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Customer deposits				150					150
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and one solar plus battery facility and three wind facilities | Subsidiaries of NextEra Energy Resources | Differential Memberships
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Customer deposits				101					101
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and one solar plus battery facility and three wind facilities | Subsidiaries of NextEra Energy Resources | NEP and Differential
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Customer deposits				251					251
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Battery Storage Facility | NEER [Member] | CALIFORNIA
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Battery storage facility capacity | MW					230
Disposal Group, Including Discontinued Operation, Consideration					$ 191
Disposal Group, Including Discontinued Operation, Working Capital					2
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal					87
Disposal Group, Not Discontinued Operation, Gain (Loss) On Disposal, Net Of Tax					$ 66
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Battery Storage Facility | NEER [Member] | NEP [Member] | CALIFORNIA
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold					67%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Seven wind facilities, six solar facilities and storage capacity
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal						53
Disposal Group, Not Discontinued Operation, Gain (Loss) On Disposal, Net Of Tax						$ 33
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Seven wind facilities, six solar facilities and storage capacity | Subsidiaries of NextEra Energy Resources | Third Party [Member] | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold						50%				50%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Seven wind facilities, six solar facilities and storage capacity | Subsidiaries of NextEra Energy Resources | NEP [Member] | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold						50%				50%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Seven wind facilities, six solar facilities and storage capacity | Subsidiaries of NextEra Energy Resources | NEP And Third Party | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Number Of Wind Generation Facilities | facility						7				7
Number Solar Generation Facilities | facility						6				6
Total generating facility capacity (mw) | MW						2,520
Battery storage facility capacity | MW						115
Disposal Group, Including Discontinued Operation, Consideration						$ 1,700				$ 1,700
Customer deposits						349				349
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Seven wind facilities, six solar facilities and storage capacity | Subsidiaries of NextEra Energy Resources | Differential Memberships | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Customer deposits						319				319
Disposal of Business and Interest Affiliates, Contingent Payments				117		$ 117			117	$ 117
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Seven wind facilities, six solar facilities and storage capacity | Subsidiaries of NextEra Energy Resources | Subsidiaries of NextEra Energy Resources | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold						100%				100%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Seven wind facilities, six solar facilities and storage capacity | Subsidiaries of NextEra Energy Resources | NEP , Third Party and Differential Membership | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Customer deposits						$ 668				$ 668
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind facilities and one solar facility | Subsidiaries of NextEra Energy Resources | United States, Midwest and West Regions
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Number Of Wind Generation Facilities | facility						3				3
Number Solar Generation Facilities | facility						1				1
Total generating facility capacity (mw) | MW										467
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind facilities and one solar facility | Subsidiaries of NextEra Energy Resources | NEP [Member] | United States, Midwest and West Regions
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold						100%				100%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Four solar facilities and multiple generation solar facilities | Subsidiaries of NextEra Energy Resources | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Number Solar Generation Facilities | facility						4				4
Total generating facility capacity (mw) | MW										122
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Four solar facilities and multiple generation solar facilities | Subsidiaries of NextEra Energy Resources | NEP [Member] | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold						33.30%				33.30%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and one solar facility and four solar facilities and multiple distributed generation solar facilities
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal										$ 94
Disposal Group, Not Discontinued Operation, Gain (Loss) On Disposal, Net Of Tax										69
Disposal Group, Including Discontinued Operation, Stockholders' Equity Attributable to Noncontrolling Interest						$ 125				125
Increase (Decrease) To Additional Paid In Capital, Gross						60				60
Increase (Decrease) To Additional Paid In Capital, Net						43				43
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and one solar facility and four solar facilities and multiple distributed generation solar facilities | NEER [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Including Discontinued Operation, Consideration						563				563
Disposal Group, Including Discontinued Operation, Working Capital						22				22
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and four solar generation facilities | subsidiary of NextEra Energy Resources [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Number Of Wind Generation Facilities | facility		3									3		3
Number Solar Generation Facilities | facility		4									4		4
Total generating facility capacity (mw) | MW											900
Disposal Group, Including Discontinued Operation, Stockholders' Equity Attributable to Noncontrolling Interest		$ 689									$ 689
Increase (Decrease) To Additional Paid In Capital, Gross		(188)									(188)
Increase (Decrease) To Additional Paid In Capital, Net		$ (165)									$ (165)
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and four solar generation facilities | subsidiary of NextEra Energy Resources [Member] | Third Party [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold		50%									50%		50%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and four solar generation facilities | subsidiary of NextEra Energy Resources [Member] | subsidiary of NextEra Energy Resources [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold		90%									90%		90%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and four solar generation facilities | subsidiary of NextEra Energy Resources [Member] | NEP [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold		40%									40%		40%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | One solar generation facility and one battery storage facility
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Battery storage facility capacity | MW											30
Solar Generating Capacity | MW											100
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | One solar generation facility and one battery storage facility | subsidiary of NextEra Energy Resources [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Customer deposits		$ 155									$ 155
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | One solar generation facility and one battery storage facility | subsidiary of NextEra Energy Resources [Member] | NEP [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Ownership percentage sold		100%									100%		100%
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Three wind generation facilities and four solar facilities and one solar generation facility and one battery storage facility | NEER [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Including Discontinued Operation, Consideration		$ 656									$ 656
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Two solar generation facilities located in Spain [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal											270
Disposal Group, Not Discontinued Operation, Gain (Loss) On Disposal, Net Of Tax											$ 270
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Two solar generation facilities located in Spain [Member] | NEER [Member]
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Number Solar Generation Facilities | facility		2									2		2
Total generating facility capacity (mw) | MW											99.8
Disposal Group, Including Discontinued Operation, Consideration		$ 121									$ 121		€ 111
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Current other liabilities | Seven wind facilities, six solar facilities and storage capacity | Subsidiaries of NextEra Energy Resources | United States, Geographically Diverse Locations
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Contract with Customer, Liability, Revenue Recognized									551
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Accounts Payable | Three wind generation facilities and one solar plus battery facility and three wind facilities
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Construction Costs				$ 810					$ 810
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Accounts Payable | Seven wind facilities, six solar facilities and storage capacity
Disposal of a Business/Assets and Sale of Noncontrolling Interest [Abstract]
Construction Costs						$ 970				$ 970

Summary of Significant Accoun_5

Summary of Significant Accounting and Reporting Policies (FPL Base Rate Agreements) (Details) - FPL [Member]			1 Months Ended	8 Months Ended	12 Months Ended		40 Months Ended	48 Months Ended	60 Months Ended
	Jan. 01, 2023 USD ($)	Jan. 01, 2022 USD ($)	Jan. 31, 2023 USD ($)	Aug. 31, 2022	Dec. 31, 2025 MW	Dec. 31, 2024 MW	Dec. 31, 2025	Dec. 31, 2025 USD ($) kWh $ / kW MW	Dec. 31, 2021 USD ($)
Accounting Policies [Line Items]
Increase in base rate revenues		$ 692,000,000
Regulatory return on common equity				10.60%					10.55%
Earned regulatory ROE threshold below which retail base rate relief may be sought				9.70%					9.60%
Earned regulatory ROE threshold above which retail base rate reduction may be sought				11.70%					11.60%
The maximum amount by which depreciation expense could be reduced (reserve)									$ 1,250,000,000
Forecast [Member]
Accounting Policies [Line Items]
Increase in base rate revenues	$ 560,000,000
SoBRA MW additions capacity | MW					894	894
SoBRA base rate revenue installed solar cap cost per unit of power | $ / kW								1,250
Contingent ROE, treasury rate, thirty year average threshold								2.49%
Contingent ROE, consecutive term								6 months
Revised Regulatory Return On Common Equity							0.1080
Revised Earned Regulatory ROE Threshold Below Which Retail Base Rate Relief May Be Sought							0.0980
Revised Earned Regulatory ROE Threshold Above Which Retail Base Rate Reduction May Be Sought							0.1180
The maximum amount by which depreciation expense could be reduced (reserve)								$ 1,450,000,000
SolarTogether MW additions capacity | MW								1,788
SolarTogether MW total capacity | MW					3,278
Time period after filing of a cost recovery petition that future storm restoration costs would be recoverable on an interim basis								60 days
Maximum storm surcharge								$ 4
Increment of usage in Kwh on which storm surcharge is based | kWh								1,000
Cost of recovery, period								12 months
Threshold of storm restoration costs in any given calendar year at which surcharge may be increased								$ 800,000,000
Customer Expected Savings, Due To The Inflation Reduction Act								$ 400,000,000
Customer Refund, Due To The Inflation Reduction Act			$ 36,000,000

Summary of Significant Accoun_6

Summary of Significant Accounting and Reporting Policies (Regulatory Assets and Liabilities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Current:
Early retirement of generation facilities and transmission assets	$ 145	$ 140
Acquisition of purchased power agreements	141	141
Deferred clause and franchise expenses	919	698
Storm restoration costs	911	92
Other	49	54
Total	2,165	1,125
Noncurrent:
Early retirement of generation facilities and transmission assets	2,026	2,233
Acquisition of purchased power agreements	191	332
Deferred clause expenses	1,227	17
Storm restoration costs	326	150
Accrued asset removal costs	532	263
Other	1,690	1,583
Total	5,992	4,578
Current:
Deferred clause revenues	339	274
Other	11	15
Total	350	289
Noncurrent:
Asset retirement obligation regulatory expense difference	3,323	4,290
Accrued asset removal costs	658	782
Deferred taxes	4,233	4,561
Other	1,412	1,640
Total	9,626	11,273
FPL [Member]
Current:
Early retirement of generation facilities and transmission assets	145	140
Acquisition of purchased power agreements	141	141
Deferred clause and franchise expenses	919	698
Storm restoration costs	911	92
Other	39	40
Total	2,155	1,111
Noncurrent:
Early retirement of generation facilities and transmission assets	2,026	2,233
Acquisition of purchased power agreements	191	332
Deferred clause expenses	1,227	17
Storm restoration costs	326	150
Accrued asset removal costs	532	263
Other	1,182	1,348
Total	5,484	4,343
Current:
Deferred clause revenues	339	274
Other	10	4
Total	349	278
Noncurrent:
Asset retirement obligation regulatory expense difference	3,323	4,290
Accrued asset removal costs	623	752
Deferred taxes	4,129	4,457
Other	1,383	1,554
Total	$ 9,458	$ 11,053
Generation Facilities And Transmission Assets
Noncurrent:
Regulatory asset, amortization period	20 years	20 years
Purchased Power Agreements
Noncurrent:
Regulatory asset, amortization period	9 years	9 years
Deferred Clause And Franchise Expenses
Noncurrent:
Regulatory asset, amortization period	21 months
Storm Restoration Costs
Noncurrent:
Regulatory asset, amortization period	12 months

Summary of Significant Accoun_7

Summary of Significant Accounting and Reporting Policies (Goodwill and Intangible Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Goodwill and Intangible Assets [Line Items]
Goodwill	$ 4,854	$ 4,844
Other intangible assets not subject to amortization, primarily land easements	136	136
Other intangible assets:
Total	722	694
Accumulated amortization	(99)	(88)
Total other intangible assets subject to amortization - net	623	606
Intangible assets, amortization [Abstract]
Amortization expense	18	25	$ 27
Amortization Expense Year 1	20
Amortization Expense Year 2	22
Amortization Expense Year 3	20
Amortization Expense Year 4	22
Amortization Expense Year 5	$ 20
Purchased Power Agreements [Member]
Other intangible assets:
Weighted average useful lives (years)	16 years
Total	$ 549	507
Other, primarily transmission and development rights and customer lists [Member]
Other intangible assets:
Weighted average useful lives (years)	24 years
Total	$ 173	187
Rate-Regulated Transmission [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	1,218	1,206
Gas Infrastructure, primarily Texas pipelines [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	487	487
Customer Supply [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	95	95
Generation Assets [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	54	56
Other Goodwill Assets [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	11	11
FPL [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	$ 2,989	$ 2,989

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 23,000	$ 18,800	$ 17,000
FPL [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	17,200	14,100	$ 13,000
Unbilled revenues	661	$ 583
Revenue, remaining performance obligation	$ 390
FPL [Member] | Revenue Benchmark [Member] | Customer Concentration Risk | Retail Customer
Disaggregation of Revenue [Line Items]
Concentration risk, percentage	90%
NEER [Member]
Disaggregation of Revenue [Line Items]
Revenue not recognized	$ 180
Revenue, remaining performance obligation	$ 1,200

Derivative Instruments (Details

Derivative Instruments (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2020	Dec. 31, 2021
Derivative [Line Items]
Reclassification from AOCI, Current Period, before Tax, Attributable to Parent		$ 26,000,000
Reclassification from AOCI, Current Period, Net of Tax, Attributable to Parent		6,000,000
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ (2,000,000)
Derivative, Collateral, Obligation to Return Cash	106,000,000		$ 56,000,000
Margin Cash Collateral Not Netted Against Derivative Liabilities	268,000,000		673,000,000
FPL [Member]
Derivative [Line Items]
Derivative, Collateral, Obligation to Return Cash	0		0
Margin Cash Collateral Not Netted Against Derivative Liabilities	$ 0		$ 0
Interest rate contracts | Not Designated as Hedging Instrument [Member] | Gains (Loss) On Disposal Of Businesses/Assets - Net [Member]
Derivative [Line Items]
Reclassification from AOCI, Current Period, before Tax, Attributable to Parent		$ 23,000,000

Derivative Instruments (Balance

Derivative Instruments (Balance Sheet Disclosure) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets	$ 3,525	$ 1,824
Derivative Liabilities	5,011	2,976
Derivative Asset, Current	1,590	689
Derivative Asset, Noncurrent	1,935	1,135
Derivative Liability, Current	2,102	1,263
Derivative Liability, Noncurrent	2,909	1,713
Current derivative assets
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Margin cash collateral received from counterparties	299	150
Non Current Derivative Assets Member
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Margin cash collateral received from counterparties	262	56
Current derivative liabilities
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Margin cash collateral paid to counterparties	328	6
Noncurrent derivative liabilities
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Margin cash collateral paid to counterparties	1,213	172
Commodity contracts | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative assets, Netting	(12,030)	(6,622)
Derivative liability, Netting	(13,010)	(6,594)
Derivative Assets	2,995	1,757
Derivative Liabilities	4,743	2,198
Commodity contracts | Level 1 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	5,372	1,896
Total derivative liabilities	7,185	2,571
Commodity contracts | Level 2 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	7,559	5,082
Total derivative liabilities	7,620	4,990
Commodity contracts | Level 3 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	2,094	1,401
Total derivative liabilities	2,948	1,231
Interest rate contracts | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative assets, Netting	(49)	(30)
Derivative liability, Netting	(49)	(30)
Derivative Assets	534	76
Derivative Liabilities	142	709
Interest rate contracts | Level 1 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	0	0
Total derivative liabilities	0	0
Interest rate contracts | Level 2 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	583	106
Total derivative liabilities	191	739
Interest rate contracts | Level 3 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	0	0
Total derivative liabilities	0	0
Foreign currency contracts | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative assets, Netting	(4)	(17)
Derivative liability, Netting	(4)	(17)
Derivative Assets	(4)	(9)
Derivative Liabilities	126	69
Foreign currency contracts | Level 1 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	0	0
Total derivative liabilities	0	0
Foreign currency contracts | Level 2 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	0	8
Total derivative liabilities	130	86
Foreign currency contracts | Level 3 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	0	0
Total derivative liabilities	0	0
FPL [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets	29
Derivative Liabilities	13	10
Derivative Asset, Current	19	13
Derivative Asset, Noncurrent	10
Derivative Liability, Current	12	9
Derivative Liability, Noncurrent	$ 1	$ 1
Derivative Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other	Other
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration]	Other	Other
Derivative Asset, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other
Derivative Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other	Other
FPL [Member] | Commodity contracts | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative assets, Netting	$ (7)	$ (3)
Derivative liability, Netting	(7)	(3)
Derivative Assets	29	13
Derivative Liabilities	13	10
FPL [Member] | Commodity contracts | Level 1 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	0	0
Total derivative liabilities	0	0
FPL [Member] | Commodity contracts | Level 2 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	11	3
Total derivative liabilities	4	8
FPL [Member] | Commodity contracts | Level 3 | Fair Value, Recurring [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Total derivative assets	25	13
Total derivative liabilities	$ 16	$ 5

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities (Significant Unobservable Inputs) (Details) - Level 3	12 Months Ended
	Dec. 31, 2022 USD ($)
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Assets, Fair Value Disclosure	$ 2,094,000,000
Liabilities, Fair Value Disclosure	2,948,000,000
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	564
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	(9)
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	51
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	222,000,000
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	23
Forward contracts - Gas [Member] | Forward contracts - Gas [Member] | Forward Price [Member] | Minimum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	2
Forward contracts - Gas [Member] | Forward contracts - Gas [Member] | Forward Price [Member] | Weighted Average [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit	4
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	$ 349,000,000
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	90%
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	44%
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	56%
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	361%
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	32%
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	134%
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	$ 114,000,000
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	90%
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	44%
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	56%
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	298%
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	24%
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	59%
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	$ 726,000,000
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	424
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	13
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	$ 73
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	103%
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%
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	6%
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	$ 457,000,000
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	158,000,000
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	68,000,000
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	26
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	(21)
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	1
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	621,000,000
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	307,000,000
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	5,000,000
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	736,000,000
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	1,037,000,000
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	230,000,000
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	$ 12,000,000

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Reconciliation of Changes in the Fair Value) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Realized and unrealized gains (losses):
Fair Value, Net Derivative Asset (Liability), Recurring Basis, Unobservable Input Reconciliation, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Net Cash Provided by (Used in) Operating Activities	Net Cash Provided by (Used in) Operating Activities	Net Cash Provided by (Used in) Operating Activities
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	$ 170	$ 1,374	$ 1,207
Realized and unrealized gains (losses):
Included in earnings	(2,343)	(1,488)	547
Included in other comprehensive income (loss)	0	0	1
Included in regulatory assets and liabilities	158	8	2
Purchases	542	243	191
Sales	0	0	114
Settlements	992	259	(562)
Issuances	(362)	(196)	(123)
Transfers in	(4)	2	18
Transfers out	(7)	(32)	(21)
Fair value of net derivatives based on significant unobservable inputs at December 31	(854)	170	1,374
Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date	(1,162)	(924)	317
Realized and unrealized gains (losses) reflected in operating revenues	(2,343)	(1,488)	569
Unrealized gains (losses) reflected in operating revenues, for derivatives still held at the reporting date	(1,162)	(924)	317
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	(1)	(8)
Realized and unrealized gains (losses):
Included in earnings	0	0	0
Included in other comprehensive income (loss)	0	0	0
Included in regulatory assets and liabilities	158	8	2
Purchases	0	0	0
Sales	0	0	0
Settlements	(157)	1	6
Issuances	0	0	0
Transfers in	0	0	(1)
Transfers out	0	0	0
Fair value of net derivatives based on significant unobservable inputs at December 31	9	8	(1)
Gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to derivatives held at the reporting date	0	$ 0	$ 0
Level 3
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Liabilities, Fair Value Disclosure	$ 2,948

Derivative Instruments (Income

Derivative Instruments (Income Statement Disclosure) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) on disposal of businesses/assets – net	$ 522	$ 77	$ 353
Not Designated as Hedging Instrument [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	(2,145)	(2,545)	(99)
Not Designated as Hedging Instrument [Member] | Commodity contracts | Gains (Losses) Included In Operating Revenues [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	(3,297)	(2,710)	352
Unrealized Gain (Loss) on Derivatives	(2,346)	(2,235)	(163)
Not Designated as Hedging Instrument [Member] | Foreign currency contracts | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	(61)	(89)	8
Unrealized Gain (Loss) on Derivatives	(53)	(89)	26
Not Designated as Hedging Instrument [Member] | Interest rate contracts | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	1,221	264	(421)
Unrealized Gain (Loss) on Derivatives	1,021	319	(396)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Not Designated as Hedging Instrument [Member] | Foreign currency contracts | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Interest Expense	(3)	(3)	(3)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Not Designated as Hedging Instrument [Member] | Interest rate contracts
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) on disposal of businesses/assets – net			23
Reclassification out of Accumulated Other Comprehensive Income [Member] | Not Designated as Hedging Instrument [Member] | Interest rate contracts | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Interest Expense	(5)	(7)	(35)
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	$ 211	$ 7	$ 6

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, 2022 USD ($) MWh MMBTU bbl	Dec. 31, 2021 USD ($) MWh MMBTU bbl
Interest Rate Swap [Member]
Derivative [Line Items]
Derivative, Notional Amount | $	$ 19.7	$ 11.2
Foreign currency contracts
Derivative [Line Items]
Derivative, Notional Amount | $	$ 1	$ 1
Short [Member] | Commodity contract - Power [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount | MWh	104	103
Short [Member] | Commodity contract - Natural gas [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	1,307	1,290
Short [Member] | Commodity contract - Oil [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount, Volume | bbl	38	33
Short [Member] | FPL [Member] | Commodity contract - Oil [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount, Volume | bbl	0	0
Long [Member] | FPL [Member] | Commodity contract - Power [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount | MWh	0	0
Long [Member] | FPL [Member] | Commodity contract - Natural gas [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	258	91

Derivative Instruments (Credit

Derivative Instruments (Credit Risk Disclosures) (Details) - USD ($)	Dec. 31, 2022	Dec. 31, 2021
Derivative [Line Items]
Liability position of derivative	$ 7,400,000,000	$ 4,100,000,000
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Bbb Or Baa2	1,625,000,000	645,000,000
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Below Investment Grade	5,200,000,000	2,700,000,000
Additional Collateral Aggregate Fair Value Due To Other Financial Measures	1,100,000,000	1,000,000,000
Collateral Already Posted, Aggregate Fair Value	59,000,000	84,000,000
Letters Of Credit Already Posted Aggregate Fair Value	1,200,000,000	1,100,000,000
FPL [Member]
Derivative [Line Items]
Liability position of derivative	15,000,000	12,000,000
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Bbb Or Baa2	0	0
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Below Investment Grade	20,000,000	35,000,000
Additional Collateral Aggregate Fair Value Due To Other Financial Measures	185,000,000	145,000,000
Collateral Already Posted, Aggregate Fair Value	0	0
Letters Of Credit Already Posted Aggregate Fair Value	$ 0	$ 0

Non-Derivative Fair Value Mea_3

Non-Derivative Fair Value Measurements (Assets and Liabilities Measured on a Recurring Basis) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Other Investments [Abstract]
Restricted Cash and Cash Equivalents, Statement of Financial Position [Extensible Enumeration]	Other	Other
Fair Value, Recurring [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	$ 961	$ 176
Special use funds [Abstract]
Equity securities	4,437	5,511
U.S. Government and municipal bonds	704	845
Corporate debt securities	722	962
Asset-backed securities	615	663
Other debt securities	20	35
Other Investments [Abstract]
Equity securities	31	72
Debt securities	535	285
Level 1 | Fair Value, Recurring [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	961	176
Restricted cash	69	56
Special use funds [Abstract]
Equity securities	2,062	2,538
U.S. Government and municipal bonds	641	770
Corporate debt securities	6	7
Asset-backed securities	0	0
Other debt securities	1	2
Other Investments [Abstract]
Equity securities	30	70
Debt securities	117	111
Level 2 | Fair Value, Recurring [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	0	0
Special use funds [Abstract]
Equity securities	2,375	2,973
U.S. Government and municipal bonds	63	75
Corporate debt securities	716	955
Asset-backed securities	615	663
Other debt securities	19	33
Other Investments [Abstract]
Equity securities	1	2
Debt securities	300	162
Level 3 | 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
Asset-backed securities	0	0
Other debt securities	0	0
Other Investments [Abstract]
Equity securities	0	0
Debt securities	$ 118	$ 12
FPL [Member]
Other Investments [Abstract]
Restricted Cash and Cash Equivalents, Statement of Financial Position [Extensible Enumeration]	Other	Other
FPL [Member] | Fair Value, Recurring [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	$ 36	$ 58
Special use funds [Abstract]
Equity securities	2,905	3,552
U.S. Government and municipal bonds	534	668
Corporate debt securities	553	726
Asset-backed securities	473	515
Other debt securities	12	25
Other Investments [Abstract]
Equity securities	9	13
Debt securities	114
FPL [Member] | Level 1 | Fair Value, Recurring [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	36	58
Restricted cash	33	53
Special use funds [Abstract]
Equity securities	743	862
U.S. Government and municipal bonds	505	624
Corporate debt securities	6	6
Asset-backed securities	0	0
Other debt securities	1	2
Other Investments [Abstract]
Equity securities	9	13
Debt securities	0
FPL [Member] | Level 2 | Fair Value, Recurring [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	0	0
Special use funds [Abstract]
Equity securities	2,162	2,690
U.S. Government and municipal bonds	29	44
Corporate debt securities	547	720
Asset-backed securities	473	515
Other debt securities	11	23
Other Investments [Abstract]
Equity securities	0	0
Debt securities	114
FPL [Member] | Level 3 | 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
Asset-backed securities	0	0
Other debt securities	0	0
Other Investments [Abstract]
Equity securities	0	$ 0
Debt securities	$ 0

Non-Derivative Fair Value Mea_4

Non-Derivative Fair Value Measurements - Contingent Consideration (Details) - GridLiance [Member] - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Mar. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration, liability			$ 264
NEER [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration, liability	$ 203	$ 261

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, 2022	Dec. 31, 2021
Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	$ 998	$ 906
Other investments	221	26
Long-term debt, including current portion	61,889	52,745
Estimated Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	999	907
Other investments	221	26
Long-term debt, including current portion	57,892	57,290
FPL [Member] | Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	744	672
Long-term debt, including current portion	21,002	18,510
FPL [Member] | Estimated Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	744	672
Long-term debt, including current portion	$ 19,364	$ 21,379

Non-Derivative Fair Value Mea_6

Non-Derivative Fair Value Measurements (Nonrecurring Fair Value Measurements) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2022	Dec. 31, 2020	Dec. 31, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets, carrying amount		$ 91,803	$ 111,059	$ 99,348
Impairment, Long-Lived Asset, Held-for-Use, Statement of Income or Comprehensive Income [Extensible Enumeration]		Income (Loss) from Equity Method Investments
NEER [Member] | Mountain Valley Pipeline [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets, carrying amount		$ 1,900
Fair value of long-lived assets		400
Impairment of long-lived assets	$ 800	1,500
Impairment of long-lived assets, after tax	600	$ 1,200
Equity method investment write-off, carrying amount	600
Equity method investment, liability	$ 200

Non-Derivative Fair Value Mea_7

Non-Derivative Fair Value Measurements (Gains and Losses) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Schedule of Available-for-sale Securities[Line Items]
Decommissioning Fund Investments, Fair Value	$ 7,495	$ 8,846
Special Use Funds Storm Fund Assets	1	76
Debt securities, amortized cost	$ 2,858	2,438
Special Use Funds Nuclear Decommissioning Funds Weighted Average Maturity	9 years
Special Use Funds Other Investments Weighted Average Maturity	7 years
Debt Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
Realized gains	$ 30	78	$ 110
Realized losses	141	73	70
Proceeds from sale and maturity of Available-for-sale Securities	2,207	1,831	2,541
Available for sale securities: Special Use Funds - Debt Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
Unrealized gains	4	76
Unrealized losses	285	19
Fair Value	2,315	1,100
FPL [Member]
Schedule of Available-for-sale Securities[Line Items]
Decommissioning Fund Investments, Fair Value	5,220	6,082
Special Use Funds Storm Fund Assets	1	76
Debt securities, amortized cost	$ 1,873	1,877
Special Use Funds Nuclear Decommissioning Funds Weighted Average Maturity	9 years
FPL [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
Realized gains	$ 24	59	83
Realized losses	111	57	56
Proceeds from sale and maturity of Available-for-sale Securities	1,371	1,330	2,162
FPL [Member] | Available for sale securities: Special Use Funds - Debt Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
Unrealized gains	3	63
Unrealized losses	193	15
Fair Value	1,466	857
Equity Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
marketable securities, unrealized gain (loss) recognized during the period on securities still held	(1,028)	981	627
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	$ (677)	$ 652	$ 444

Fair Value Measures and Disclos

Fair Value Measures and Disclosures (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Trading securities, cost	$ 485	$ 72

Income Taxes - Components of In

Income Taxes - Components of Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Federal:
Current	$ 11	$ (26)	$ 105
Deferred	497	311	(148)
Total federal	508	285	(43)
State:
Current	41	(62)	18
Deferred	37	125	69
Total state	78	63	87
Total income taxes	586	348	44
FPL [Member]
Federal:
Current	3	85	16
Deferred	684	545	474
Total federal	687	630	490
State:
Current	2	1	32
Deferred	258	207	156
Total state	260	208	188
Total income taxes	$ 947	$ 838	$ 678

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Operating Loss Carryforwards [Line Items]
Statutory federal income tax rate	21%	21%	21%
Increases (reductions) resulting from:
State income taxes – net of federal income tax benefit	1.60%	1.60%	2.80%
Taxes attributable to noncontrolling interests	4.90%	5%	4.80%
PTCs and ITCs	(6.80%)	(11.30%)	(12.70%)
Amortization of deferred regulatory credit	(4.80%)	(4.40%)	(7.20%)
Foreign operations(a)	0.10%	0.20%	(2.40%)
Other – net	(0.70%)	(1.10%)	(4.50%)
Effective income tax rate (in hundredths)	15.30%	11%	1.80%
FPL [Member]
Operating Loss Carryforwards [Line Items]
Statutory federal income tax rate	21%	21%	21%
Increases (reductions) resulting from:
State income taxes – net of federal income tax benefit	4.40%	4.10%	4.20%
Taxes attributable to noncontrolling interests	0%	0%	0%
PTCs and ITCs	(1.10%)	(0.70%)	(0.60%)
Amortization of deferred regulatory credit	(4.00%)	(3.50%)	(4.90%)
Foreign operations(a)	0%	0%	0%
Other – net	0.10%	(0.20%)	(0.70%)
Effective income tax rate (in hundredths)	20.40%	20.70%	19%

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Deferred tax liabilities:
Property-related	$ 10,144	$ 10,018
Pension	552	564
Investments in partnerships and joint ventures	3,144	2,783
Other	2,666	2,092
Total deferred tax liabilities	16,506	15,457
Deferred tax assets and valuation allowance:
Decommissioning reserves	306	296
Net operating loss carryforwards	346	330
Tax credit carryforwards	4,905	4,646
ARO and accrued asset removal costs	199	199
Regulatory liabilities	1,332	1,421
Other	822	733
Valuation allowance	(257)	(282)
Net deferred tax assets	7,653	7,343
Net deferred income taxes	8,853	8,114
Deferred tax assets and liabilities included in the consolidated balance sheets [Abstract]
Noncurrent other assets	219	196
Deferred income taxes – noncurrent liabilities	(9,072)	(8,310)
Net deferred income taxes	(8,853)	(8,114)
FPL [Member]
Deferred tax liabilities:
Property-related	8,177	7,831
Pension	439	425
Investments in partnerships and joint ventures	3	3
Other	1,914	1,232
Total deferred tax liabilities	10,533	9,491
Deferred tax assets and valuation allowance:
Decommissioning reserves	306	296
Net operating loss carryforwards	19	2
Tax credit carryforwards	123	182
ARO and accrued asset removal costs	107	126
Regulatory liabilities	1,308	1,397
Other	295	351
Valuation allowance	0	0
Net deferred tax assets	2,158	2,354
Net deferred income taxes	8,375	7,137
Deferred tax assets and liabilities included in the consolidated balance sheets [Abstract]
Noncurrent other assets	1	0
Deferred income taxes – noncurrent liabilities	(8,376)	(7,137)
Net deferred income taxes	$ (8,375)	$ (7,137)

Income Taxes - Tax Carryforward

Income Taxes - Tax Carryforwards and Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	$ 346	$ 330
Tax credit carryforwards	4,905	$ 4,646
Federal [Member]
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	11
Tax credit carryforwards	4,555
Net operating loss carryforwards with indefinite expiration period	9
State [Member]
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	315
Tax credit carryforwards	345
Tax credit carryforward with indefinite expiration period	191
Foreign [Member]
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	20
Tax credit carryforwards	5
Net operating loss carryforwards with indefinite expiration period	$ 1

Income Taxes (Details)

Income Taxes (Details) $ in Millions	Jan. 31, 2023 USD ($)
Subsequent Event
Operating Loss and Tax Credit Carryforwards [Line Items]
Revenue not recognized	$ 36

Acquisitions (Details)

Acquisitions (Details) $ in Millions	Oct. 27, 2022 USD ($) numberOfProjects	Mar. 31, 2021 USD ($) state utlity mi	Dec. 31, 2022 USD ($) county	Dec. 31, 2021 USD ($)	Jan. 01, 2021 USD ($)
Business Acquisition [Line Items]
Goodwill			$ 4,854	$ 4,844
Gulf Power [Member]
Business Acquisition [Line Items]
Debt assumed					$ 1,800
Assets assumed					6,700
Property, plant, and equipment					4,900
Regulatory assets					1,200
Assumed liabilities					3,900
Regulatory liabilities					566
Deferred income taxes					729
GridLiance [Member]
Business Acquisition [Line Items]
Assets assumed		$ 384
Assumed liabilities		210
Goodwill		592
Goodwill, expected tax deductible amount		586
Cash consideration		502
Business combination, assumption of debt		175
Contingent consideration, liability		$ 264
FPL [Member]
Business Acquisition [Line Items]
Number of counties In which entity operates | county			8
Goodwill			$ 2,989	2,989
FPL [Member] | Gulf Power [Member]
Business Acquisition [Line Items]
Goodwill					$ 2,700
GridLiance Holdco, LP and GridLiance GP, LLC | GridLiance [Member]
Business Acquisition [Line Items]
Length of power lines (mi) | mi		700
Number Of FERC-Regulated Transmission Utilities | utlity		3
Number of States in which Entity Operates | state		6
GridLiance Holdco, LP and GridLiance GP, LLC | GridLiance [Member] | Midwest And Nevada [Member]
Business Acquisition [Line Items]
Number of States in which Entity Operates | state		5
NEER [Member] | GridLiance [Member]
Business Acquisition [Line Items]
Contingent consideration, liability			$ 203	$ 261
NEER [Member] | RNG Acquisition
Business Acquisition [Line Items]
Cash consideration	$ 1,100
Business combination, assumption of debt	$ 37
Membership interests acquired	100%
Number of RNG projects | numberOfProjects	31
Number Of RNG Projects, Renewable Gas Facility | numberOfProjects	1

Property, Plant and Equipment -

Property, Plant and Equipment - Schedule Of Property Plant and Equipment (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Electric plant in service and other property	$ 124,963	$ 112,500
Nuclear fuel	1,684	1,606
Construction work in progress	15,675	14,141
Property, plant and equipment, gross	142,322	128,247
Accumulated depreciation and amortization	(31,263)	(28,899)
Property, plant and equipment - net	111,059	99,348	$ 91,803
FPL [Member]
Property, Plant and Equipment [Line Items]
Electric plant in service and other property	74,353	67,771
Nuclear fuel	1,190	1,170
Construction work in progress	7,026	6,326
Property, plant and equipment, gross	82,569	75,267
Accumulated depreciation and amortization	(17,876)	(17,040)
Electric utility plant and other property – net	$ 64,693	$ 58,227

Property, Plant and Equipment_2

Property, Plant and Equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Property, plant and equipment – net	$ 111,059	$ 99,348	$ 91,803
FPL [Member]
Property, Plant and Equipment [Line Items]
Amount of reserve (reversal) amortization recognized	114	429	(1)
AFUDC capitalized	$ 136	$ 176	$ 117
FPL [Member]
Property, Plant and Equipment [Line Items]
Percentage of electric generating assets to gross investment in electric utility plant in service (in hundredths)	44%	46%
Percentage of electric transmission assets to gross investment in electric utility plant in service (in hundredths)	14%	13%
Percentage of electric distribution assets to gross investment in electric utility plant in service (in hundredths)	35%	35%
Percentage of general facilities assets to gross investment in electric utility plant in service (in hundredths)	7%	6%
FPL's composite depreciation rate for electric plant in service (in hundredths)	3.60%	3.80%	3.80%
AFUDC equity component	$ 105	$ 132	$ 87
FPL [Member] | St. Lucie Unit No. 2
Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	85%
Gross Investment	$ 2,276
Accumulated Depreciation	1,062
Construction Work in Progress	$ 163
FPL [Member] | Daniel Units Nos. 1 and 2
Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	50%
Gross Investment	$ 753
Accumulated Depreciation	285
Construction Work in Progress	$ 22
FPL [Member] | Scherer Unit No. 3
Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	25%
Gross Investment	$ 405
Accumulated Depreciation	169
Construction Work in Progress	1
NEER [Member]
Property, Plant and Equipment [Line Items]
Net Book Value Of Assets Serving As Collateral	14,400
Interest capitalized on construction projects of NEER	$ 172	$ 139	$ 168
NEER [Member] | Wind plants [Member]
Property, Plant and Equipment [Line Items]
Percentage of gross depreciable assets by plant type	51%	53%
NEER [Member] | Wind plants [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, estimated useful lives (in years)	30 years
NEER [Member] | Wind plants [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, estimated useful lives (in years)	35 years
NEER [Member] | Solar plants [Member]
Property, Plant and Equipment [Line Items]
Percentage of gross depreciable assets by plant type	14%	14%
NEER [Member] | Solar plants [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, estimated useful lives (in years)	30 years
NEER [Member] | Solar plants [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, estimated useful lives (in years)	35 years
NEER [Member] | Oil and Gas Properties [Member]
Property, Plant and Equipment [Line Items]
Percentage of gross depreciable assets by plant type	15%	14%
NEER [Member] | Nuclear Plant [Member]
Property, Plant and Equipment [Line Items]
Percentage of gross depreciable assets by plant type	7%	8%
NEER [Member] | Nuclear Plant [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, estimated useful lives (in years)	23 years
NEER [Member] | Nuclear Plant [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, estimated useful lives (in years)	47 years
NEER [Member] | Seabrook
Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	88.23%
Gross Investment	$ 1,355
Accumulated Depreciation	494
Construction Work in Progress	$ 74
NEER [Member] | Wyman Station Unit No. 4
Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	91.19%
Gross Investment	$ 31
Accumulated Depreciation	12
Construction Work in Progress	$ 0
NEER [Member] | Stanton
Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	65%
Gross Investment	$ 139
Accumulated Depreciation	25
Construction Work in Progress	$ 0
NEER [Member] | Transmission substation assets located in Seabrook, New Hampshire
Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	88.23%
Gross Investment	$ 140
Accumulated Depreciation	4
Construction Work in Progress	$ 4

Equity Method Investments (Deta

Equity Method Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Equity method investment, financial statement, reported amounts [Abstract]
NextEra Energy Resources' ownership interest, low range (in hundredths)	43%
NextEra Energy Resources' ownership interest, high range (in hundredths)	54%
Equity method investment, summarized financial information [Abstract]
Operating revenue	$ 20,956	$ 17,069	$ 17,997
Operating income	4,081	2,913	5,116
Net income	(901)	(746)	(550)
Total assets	158,935	140,912	127,684
Total liabilities	109,499	95,243
Investment in equity method investees	6,582	6,159	5,728
Interest and Fee Income, Other Loans	174	148	120
Due from Related Parties, Current	94	113
Due from Related Parties, Noncurrent	101	40
Guarantor Obligations, Current Carrying Value	495
FPL [Member]
Equity method investment, summarized financial information [Abstract]
Related Party Services	579	691	$ 721
Equity Method Investment, Nonconsolidated Investee, Other
Equity method investment, summarized financial information [Abstract]
Operating revenue	1,705	1,469
Operating income	1,423	559
Net income	1,380	739
Total assets	26,058	29,537
Total liabilities	9,779	9,501
Partners'/members' equity	16,279	20,036
NEER [Member]
Equity method investment, summarized financial information [Abstract]
NEE's share of underlying equity in the principal entities	2,379	4,352
Difference between investment carrying amount and underlying equity in net assets	2,589	1,133
Investment in equity method investees	4,968	5,485
NEP OpCo [Member]
Equity method investment, summarized financial information [Abstract]
Difference between investment carrying amount and underlying equity in net assets	$ 2,500	2,600
Difference related to goodwill	75%
NEP [Member]
Equity method investment, summarized financial information [Abstract]
Due to Related Parties	$ 298	57
Guarantor Obligations, Current Carrying Value	4,600
Guarantees, Fair Value Disclosure	$ 56
Mountain Valley Pipeline [Member]
Equity method investment, summarized financial information [Abstract]
Difference between investment carrying amount and underlying equity in net assets		$ 1,500
Minimum [Member] | NEP OpCo [Member]
Equity method investment, summarized financial information [Abstract]
Amortization period	13 years
Maximum [Member] | NEP OpCo [Member]
Equity method investment, summarized financial information [Abstract]
Amortization period	25 years

Variable Interest Entities (V_2

Variable Interest Entities (VIEs) (Details) $ in Millions	3 Months Ended	6 Months Ended	12 Months Ended
	Dec. 31, 2022 USD ($) variable_interest_entity MW	Jun. 30, 2023 MW	Dec. 31, 2022 USD ($) variable_interest_entity mi MW	Dec. 31, 2021 USD ($) variable_interest_entity	Dec. 31, 2020 USD ($)
Variable Interest Entity [Line Items]
TOTAL ASSETS	$ 158,935		$ 158,935	$ 140,912	$ 127,684
Carrying amount of liabilities, consolidated variable interest entity	109,499		109,499	95,243
Investment in equity method investees	6,582		6,582	6,159	$ 5,728
Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
TOTAL ASSETS	744		744	614
Carrying amount of liabilities, consolidated variable interest entity	18		$ 18	64
Electricity Transmission Line | mi			280
Variable Interest Entity, Consolidated, Income Allocation, Percentage			50%
Variable Interest Entity Other [Member]
Variable Interest Entity [Line Items]
Investments in special purpose entities	$ 4,016		$ 4,016	$ 4,559
Indirect Subsidiary of NextEra Energy Resources [Member] | Photovoltaic Solar Facility [Member]
Variable Interest Entity [Line Items]
Total Number Of Consolidated Variable Interest Entities | variable_interest_entity	9		9	8
TOTAL ASSETS	$ 2,084		$ 2,084	$ 1,851
Carrying amount of liabilities, consolidated variable interest entity	1,174		$ 1,174	1,258
Solar generating facility capability | MW			772
Indirect Subsidiary of NextEra Energy Resources [Member] | Photovoltaic Solar Facility [Member] | Forecast [Member]
Variable Interest Entity [Line Items]
Solar generating facility capability | MW		125
Battery storage facility capacity | MW		65
Indirect Subsidiary of NextEra Energy Resources [Member] | Photovoltaic Solar Facility [Member] | Minimum [Member]
Variable Interest Entity [Line Items]
Ownership percentage (in hundredths)			50%
Indirect Subsidiary of NextEra Energy Resources [Member] | Photovoltaic Solar Facility [Member] | Maximum [Member]
Variable Interest Entity [Line Items]
Ownership percentage (in hundredths)			67%
NextEra Energy Resources Consolidated VIE [Member] | 10% direct ownership in wind and solar facilities
Variable Interest Entity [Line Items]
TOTAL ASSETS	1,488		$ 1,488	1,518
Carrying amount of liabilities, consolidated variable interest entity	$ 86		86	79
Ownership percentage (in hundredths)	10%
Wind electric generating facility capability (in megawatts) | MW	400
Solar generating facility capability | MW	599
NEER [Member]
Variable Interest Entity [Line Items]
Investment in equity method investees	$ 4,968		$ 4,968	5,485
NEER [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Wind electric generating facility capability (in megawatts) | MW			12,413
Solar generating facility capability | MW			2,360
NEER [Member] | Variable Interest Entities Wind and Solar Primary Beneficiary [Member] [Member]
Variable Interest Entity [Line Items]
TOTAL ASSETS	19,690		$ 19,690	17,419
Carrying amount of liabilities, consolidated variable interest entity	2,318		$ 2,318	1,480
Wind electric generating facility capability (in megawatts) | MW			11,712
Solar generating facility capability | MW			600
Battery storage facility capacity | MW			324
NEER [Member] | Variable Interest Entities Wind and Solar Primary Beneficiary [Member] [Member] | Forecast [Member]
Variable Interest Entity [Line Items]
Wind electric generating facility capability (in megawatts) | MW		301
Solar generating facility capability | MW		1,161
Battery storage facility capacity | MW		390
FPL [Member]
Variable Interest Entity [Line Items]
TOTAL ASSETS	86,559		$ 86,559	78,067
Carrying amount of liabilities, consolidated variable interest entity	47,639		47,639	44,473
FPL [Member] | Variable Interest Entity Other [Member]
Variable Interest Entity [Line Items]
Investments in special purpose entities	3,331		3,331	3,799
Other Investments [Member] | Subsidiaries of NEE [Member]
Variable Interest Entity [Line Items]
Investment in equity method investees	5,214		5,214	$ 4,214
Commitments To Increase (Decrease) In Equity Method Investments	$ 180		$ 180

Leases (Details)

Leases (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($) agreement	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Lessee, Lease, Description [Line Items]
Number Of Land Use Agreements | agreement	3
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other	Other	Other
Operating Lease, Liability, Statement of Financial Position [Extensible List]	Other Liabilities	Other Liabilities	Other Liabilities
ROU assets, operating leases	$ 386	$ 547
Lease liabilities, operating leases	$ 400	$ 555
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other	Other	Other
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Liabilities	Other Liabilities	Other Liabilities
ROU assets, finance leases	$ 378	$ 205
Lease liabilities, finance leases	$ 375	$ 200
Weighted average incremental borrowing rate at the lease inception, operating leases	3.66%	3.57%
Weighted average incremental borrowing rate at the lease inception, finance leases	3.98%	3.52%
Weighted-average remaining lease term, operating leases	45 years	39 years
Weighted-average remaining lease term, finance leases	33 years	31 years
Expected lease payments over the remaining terms of the leases	$ 1,600
Operating Lease, Expense	70	$ 92	$ 95
Net investment in sales-type leases	53	$ 42
Operating and Sales-type Leases, Lease Receivable, Payments to be Received	$ 1,100
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, 2022	Dec. 31, 2021
Asset retirement obligation, roll forward analysis [Roll Forward]
Beginning balance	$ 3,179	$ 3,166
Liabilities incurred	82	79
Accretion expense	145	141
Liabilities settled	(80)	(88)
Revision in estimated cash flows – net	2	(119)
Ending balance	3,328	3,179
Current portion	83	97
Liabilities settled related to project sales and other disposals	27	35
Restricted funds included in special use funds [Abstract]
Restricted funds	$ 7,495	8,846
St. Lucie Units Number One
Asset retirement obligation, roll forward analysis [Roll Forward]
License renewal period	20 years
St. Lucie Units Number Two
Asset retirement obligation, roll forward analysis [Roll Forward]
License renewal period	20 years
FPL [Member]
Asset retirement obligation, roll forward analysis [Roll Forward]
Beginning balance	$ 2,107	1,936
Liabilities incurred	0	7
Accretion expense	81	78
Liabilities settled	(22)	(15)
Revision in estimated cash flows – net	10	101
Ending balance	2,176	2,107
Current portion	68	58
Restricted funds included in special use funds [Abstract]
Restricted funds	$ 5,220	$ 6,082
FPL [Member] | St. Lucie Units Number Two
Asset retirement obligation, roll forward analysis [Roll Forward]
License renewal period	20 years

Employee Retirement Benefits -

Employee Retirement Benefits - Plan Assets, Benefit Obligations and Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Other Postretirement Benefits Plan [Member]
Change in pension benefit obligation:
Service cost	$ 1	$ 2	$ 1
Interest cost	5	4	8
Special termination benefits	0	0	0
Funded status:
Prepaid (accrued) benefit cost	(237)	(300)
Pension Benefits [Member]
Change in pension plan assets:
Plan assets, beginning balance	5,688	5,314
Actual return on plan assets	(820)	627
Benefit payments	(325)	(253)
Plan assets, ending balance	4,543	5,688	5,314
Change in pension benefit obligation:
Obligation, beginning balance	3,445	3,607
Service cost	86	90	85
Interest cost	77	64	92
Special termination benefits	(52)	0	(16)
Plan amendments	(3)	0
Actuarial gains – net	(627)	(63)
Benefit payments	(325)	(253)
Obligation, ending balance	2,711	3,445	$ 3,607
Funded status:
Prepaid (accrued) benefit cost	1,832	2,243
Accumulated benefit obligation	2,650	3,352
FPL [Member] | Other Postretirement Benefits Plan [Member]
Funded status:
Prepaid (accrued) benefit cost	(115)	(139)
FPL [Member] | Pension Benefits [Member]
Funded status:
Prepaid (accrued) benefit cost	$ 1,732	$ 1,657

Employee Retirement Benefits _2

Employee Retirement Benefits - Unrecognized Amounts (Details) - Pension Benefits [Member] - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Components of AOCI:
Unrecognized prior service benefit	$ 1	$ 2
Unrecognized losses	(91)	41
Total	(90)	43
Tax effects on components of AOCI [Abstract]
Tax expense (benefit) related to unrecognized prior service benefit (cost)	0	1
Tax expense (benefit) related to unrecognized gain (loss)	(33)	7
Unrecognized amounts included in regulatory assets (liabilities) [Abstract]
Unrecognized prior service cost (benefit)	2	(1)
Unrecognized losses (gains)	277	(80)
Total	$ 279	$ (81)

Employee Retirement Benefits _3

Employee Retirement Benefits - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Target asset allocations [Abstract]
Defined contribution expense	$ 68	$ 66	$ 64
Pension Benefits [Member]
Weighted-average assumptions used to determine benefit obligations [Abstract]
Discount rate (in hundredths)	5.05%	2.87%
Salary increase (in hundredths)	4.90%	4.90%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Weighted-Average Interest Crediting Rate	3.82%	3.79%
Pension Benefits [Member] | Equity Securities [Member]
Target asset allocations [Abstract]
Equity investments, target allocation percentage (in hundredths)	43%
Pension Benefits [Member] | Debt Securities [Member]
Target asset allocations [Abstract]
Equity investments, target allocation percentage (in hundredths)	32%
Pension Benefits [Member] | Alternative Investments [Member]
Target asset allocations [Abstract]
Equity investments, target allocation percentage (in hundredths)	20%
Pension Benefits [Member] | Convertible Securities [Member]
Target asset allocations [Abstract]
Equity investments, target allocation percentage (in hundredths)	5%
FPL [Member]
Target asset allocations [Abstract]
Defined contribution expense	$ 41	$ 42	$ 40

Employee Retirement Benefits _4

Employee Retirement Benefits - Fair Value of Pension Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Fair Value Measured at Net Asset Value Per Share
Fair value measurements of plan assets [Abstract]
Foreign investments	$ 242	$ 220
Equity Securities [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	526	927
Equity Securities [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	1,252	2,008
Equity Securities [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	1,246	1,977
Equity Securities [Member] | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	5	29
Equity Securities [Member] | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	1	2
Equity Commingled Vehicles [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	191	169
Equity Commingled Vehicles [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	731	889
Equity Commingled Vehicles [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Equity Commingled Vehicles [Member] | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	731	889
Equity Commingled Vehicles [Member] | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
U.S. Government And Municipal Bonds [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	90	137
U.S. Government And Municipal Bonds [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	85	131
U.S. Government And Municipal Bonds [Member] | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	5	6
U.S. Government And Municipal Bonds [Member] | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Corporate debt securities [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	83	109
Corporate debt securities [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	272	351
Corporate debt securities [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Corporate debt securities [Member] | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	272	351
Corporate debt securities [Member] | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Asset-backed securities [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	413	386
Asset-backed securities [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Asset-backed securities [Member] | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	413	386
Asset-backed securities [Member] | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Debt Security Commingled Vehicles [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	129
Debt Security Commingled Vehicles [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	130	219
Debt Security Commingled Vehicles [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Debt Security Commingled Vehicles [Member] | Level 2
Fair value measurements of plan assets [Abstract]
Fair value	130	219
Debt Security Commingled Vehicles [Member] | Level 3
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Convertible securities [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	30	5
Convertible securities [Member] | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	417	580
Convertible securities [Member] | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	50	91
Convertible securities [Member] | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	367	489
Convertible securities [Member] | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Investments measured at net asset value [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments		41
Total Investments
Fair value measurements of plan assets [Abstract]
Fair value	4,543	5,688
Total Investments | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	3,305	4,570
Total Investments | Level 1 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	1,381	2,199
Total Investments | Level 2 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	1,923	2,369
Total Investments | Level 3 | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	1	2
Total Investments | Fair Value Measured at Net Asset Value Per Share | Carrying Amount
Fair value measurements of plan assets [Abstract]
Fair value	$ 1,238	$ 1,118

Employee Retirement Benefits _5

Employee Retirement Benefits - Expected Cash Flows (Details) - Pension Benefits [Member] $ in Millions	Dec. 31, 2022 USD ($)
Defined Benefit Plan Disclosure [Line Items]
2023	$ 198
2024	199
2025	201
2026	204
2027	203
2028 – 2032	$ 1,008

Employee Retirement Benefits _6

Employee Retirement Benefits - Net Periodic Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Pension Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Service cost	$ 86	$ 90	$ 85
Interest cost	77	64	92
Expected return on plan assets	(363)	(339)	(321)
Amortization of actuarial loss	0	24	18
Amortization of prior service benefit	(1)	(1)	(1)
Special termination benefits	52	0	16
Benefit plan settlement	27	0	0
Net periodic (income) cost	(122)	(162)	(111)
Other Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Service cost	1	2	1
Interest cost	5	4	8
Expected return on plan assets	0	0	0
Amortization of actuarial loss	3	5	3
Amortization of prior service benefit	(4)	(15)	(16)
Special termination benefits	0	0	0
Benefit plan settlement	0	0	0
Net periodic (income) cost	5	(4)	(4)
FPL [Member] | Pension Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Net periodic (income) cost	(76)	(108)	(84)
FPL [Member] | Other Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Net periodic (income) cost	$ 4	$ (4)	$ (4)

Employee Retirement Benefits _7

Employee Retirement Benefits - Net Periodic Income Cost Recognizedf for OCI (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Reclassification from accumulated other comprehensive income (loss) to net income	$ 7,000,000	$ 5,000,000	$ 2,000,000
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)	(2,000,000)	(1,000,000)	(1,000,000)
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net gains (losses)	(139,000,000)	95,000,000	42,000,000
Reclassification from accumulated other comprehensive income (loss) to net income	7,000,000	6,000,000	5,000,000
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax and Reclassification Adjustment, Attributable to Parent	(133,000,000)	101,000,000	47,000,000
Tax effects on components of net periodic income (cost) recognized in OCI [Abstract]
Net gains (losses)	(43,000,000)	29,000,000	13,000,000
Reclassification from accumulated other comprehensive income (loss) to net income, tax expense (benefit)	2,000,000	2,000,000	1
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), before Tax	(1,000,000)	$ 0	$ 0
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Tax	$ 0

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, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost Recognized In Regulatory Assets Liabilities	$ 2	$ (1)
Unrecognized losses (gains)	375	(226)
Amortization of prior service benefit	1	0
Amortization Of Unrecognized Losses Recognized In Regulatory Assets Liabilities	(18)	(16)
Total	$ 360	$ (243)

Employee Retirement Benefits _9

Employee Retirement Benefits - Assumptions Used for Periodic Income (Details) - Pension Benefits [Member]	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Discount rate	2.87%	2.53%	3.22%
Salary increase	4.90%	4.40%	4.40%
Expected long-term rate of return, net of management fees	7.35%	7.35%	7.35%
Weighted-average interest crediting rate	3.79%	3.82%	3.83%

Debt (Schedule of Debt Instrume

Debt (Schedule of Debt Instruments) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Current portion of long-term debt	$ 6,633	$ 1,785
Long-term debt, excluding current maturities	55,256	50,960
Repayment prior to maturity	6,633
FPL [Member]
Debt Instrument [Line Items]
Unamortized debt issuance costs and premium and discount	(203)	(191)
Total long-term debt	21,002	18,510
Current portion of long-term debt	1,547	536
Long-term debt, excluding current maturities	19,455	17,974
Repayment prior to maturity	1,547
FPL [Member] | First mortgage bonds - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 15,790	$ 14,290
Weighted-average interest rate	4.03%	4.20%
FPL [Member] | Pollution control, solid waste disposal and industrial development revenue bonds - primary variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 1,366	$ 1,407
Weighted-average interest rate	3.20%	0.15%
Variable rate tax exempt bonds	$ 1,334
FPL [Member] | Senior Unsecured Notes - Primarily Variable
Debt Instrument [Line Items]
Long-term debt, gross	$ 4,042	$ 2,697
Weighted-average interest rate	3.99%	1.37%
Floating rate notes that permit individual noteholders to require repayment prior to maturity	$ 1,327
FPL [Member] | Other long-term debt - primarily variable
Debt Instrument [Line Items]
Long-term debt, gross	$ 7	$ 307
Weighted-average interest rate	7.90%	0.82%
NEER [Member]
Debt Instrument [Line Items]
Unamortized debt issuance costs and premium and discount	$ (108)	$ (92)
Total long-term debt	9,051	7,419
Current portion of long-term debt	694	664
Long-term debt, excluding current maturities	8,357	6,755
NEER [Member] | Senior secured limited-recourse term loans - variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 3,582	$ 3,100
Weighted-average interest rate	6.24%	1.74%
NEER [Member] | Senior secured limited-recourse long-term loans - fixed
Debt Instrument [Line Items]
Long-term debt, gross	$ 2,452	$ 2,475
Weighted-average interest rate	3.43%	3.30%
NEER [Member] | Other Long-Term Debt - Primarily Variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 777	$ 785
Weighted-average interest rate	6.33%	2.50%
Capital Holdings [Member]
Debt Instrument [Line Items]
Unamortized debt issuance costs and premium and discount	$ (135)	$ (120)
Total long-term debt	31,836	26,816
Current portion of long-term debt	4,392	585
Long-term debt, excluding current maturities	27,444	26,231
Capital Holdings [Member] | Other long-term debt - primarily variable
Debt Instrument [Line Items]
Long-term debt, gross	$ 675	$ 1,245
Weighted-average interest rate	5.02%	0.64%
Capital Holdings [Member] | Other long-term debt - primarily fixed
Debt Instrument [Line Items]
Long-term debt, gross	$ 164	$ 186
Weighted-average interest rate	0.92%	0.92%
Capital Holdings [Member] | Debentures - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 17,865	$ 10,990
Weighted-average interest rate	2.99%	2.21%
Capital Holdings [Member] | Debentures variable [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 2,200	$ 3,850
Weighted-average interest rate	4.14%	0.56%
Capital Holdings [Member] | Debentures, related to NEE's equity units - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 6,500	$ 6,000
Weighted-average interest rate	2.28%	1.46%
Capital Holdings [Member] | Junior subordinated debentures - primarily fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 3,723	$ 3,723
Weighted-average interest rate	5.23%	4.54%
Capital Holdings [Member] | Japanese yen denominated long-term debt - primarily variable
Debt Instrument [Line Items]
Long-term debt, gross	$ 506	$ 582
Weighted-average interest rate	0.73%	1.49%
Capital Holdings [Member] | Australian dollar denominated long-term debt - fixed [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 338	$ 360
Weighted-average interest rate	2.20%	2.20%
NEET [Member] | Other long-term debt - primarily fixed | NEER [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 2,348	$ 1,151
Weighted-average interest rate	5.10%	2.69%

Debt (Minimum Annual Maturities

Debt (Minimum Annual Maturities) (Details) $ in Thousands	Dec. 31, 2022 USD ($)
Debt Instrument [Line Items]
Year One	$ 6,633,000
Year Two	6,848,000
Year Three	7,702,000
Year Four	1,218,000
Year Five	7,329,000
FPL [Member]
Debt Instrument [Line Items]
Year One	1,547,000
Year Two	1,646,000
Year Three	1,700,000
Year Four	200
Year Five	$ 328,000

Debt (Narrative) (Details)

Debt (Narrative) (Details) - USD ($)		1 Months Ended
	Sep. 01, 2022	Sep. 30, 2022	Sep. 30, 2020	Feb. 29, 2020	Feb. 17, 2023	Feb. 09, 2023	Dec. 31, 2022	Aug. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Weighted-average interest rate of commercial paper and short-tem borrowings (in hundredths)							4.58%		0.39%
Line of Credit Facility, Fair Value of Amount Outstanding							$ 0
Line of Credit [Member]
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity, issuance of letters of credit							17,900,000,000
Line of Credit Facility, Fair Value of Letters Of Credit Outstanding							$ 3,700,000,000
Line of Credit [Member] | Forecast [Member]
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity, issuance of letters of credit					$ 20,200,000,000
FPL [Member]
Debt Instrument [Line Items]
Weighted-average interest rate of commercial paper and short-tem borrowings (in hundredths)							4.41%		0.27%
FPL [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity, issuance of letters of credit							$ 4,500,000,000
Line of Credit Facility, Fair Value of Letters Of Credit Outstanding							$ 3,000,000
FPL [Member] | Line of Credit [Member] | Forecast [Member]
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity, issuance of letters of credit					$ 4,100,000,000
NextEra Energy Capital Holdings, Inc. [Member] | Debentures [Member] | Subsequent Event
Debt Instrument [Line Items]
Debt Instrument, Face Amount						$ 4,000,000,000
NextEra Energy Capital Holdings, Inc. [Member] | Debentures [Member] | Minimum [Member] | Subsequent Event
Sale of equity units [Abstract]
Interest rate						4.90%
NextEra Energy Capital Holdings, Inc. [Member] | Debentures [Member] | Maximum [Member] | Subsequent Event
Sale of equity units [Abstract]
Interest rate						5.25%
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%
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)							0.7132
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)							0.5703
Trading period (in days) over which the market value is determined by reference to the average closing prices of the common stock				20 days
Rate of total annual distributions on equity units (in hundredths)							5.279%
Interest rate							1.84%
Rate of payments on stock purchase contracts (in hundredths)							3.439%
NEE Equity Units February 2020 [Member] | Minimum [Member]
Sale of equity units [Abstract]
The Adjusted Reference Price (in dollars per share)							$ 70.39
NEE Equity Units February 2020 [Member] | Maximum [Member]
Sale of equity units [Abstract]
Adjusted Threshold Appreciation Price							$ 87.99
NEE Equity Units September 2020 [Member]
Sale of equity units [Abstract]
Amount of equity units sold			$ 2,000,000,000
Stated amount of each equity unit (in dollars per share)			$ 50
Undivided beneficial ownership interest per debenture (in hundredths)			5%
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)							0.6802
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)							0.5442
Trading period (in days) over which the market value is determined by reference to the average closing prices of the common stock			20 days
Rate of total annual distributions on equity units (in hundredths)							6.219%
Interest rate							0.509%
Rate of payments on stock purchase contracts (in hundredths)							5.71%
NEE Equity Units September 2020 [Member] | Minimum [Member]
Sale of equity units [Abstract]
The Adjusted Reference Price (in dollars per share)							$ 73.79
NEE Equity Units September 2020 [Member] | Maximum [Member]
Sale of equity units [Abstract]
Adjusted Threshold Appreciation Price							$ 92.24
NEE Equity Units September 2022
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%
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)							0.5626
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)							0.4500
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)							6.926%
Interest rate							4.60%
Rate of payments on stock purchase contracts (in hundredths)							2.326%
NEE Equity Units September 2022 | Minimum [Member]
Sale of equity units [Abstract]
The Adjusted Reference Price (in dollars per share)							$ 88.88
NEE Equity Units September 2022 | Maximum [Member]
Sale of equity units [Abstract]
Adjusted Threshold Appreciation Price							$ 111.10
Series J Debentures due 2024 | NextEra Energy Capital Holdings, Inc. [Member] | Debentures [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount								$ 1,500,000,000
Sale of equity units [Abstract]
Interest rate		4.255%
September 2019 Equity Units
Sale of equity units [Abstract]
Sale of Stock, Number of Shares Issued in Transaction	21,600,000
Sale of Stock, Consideration Received on Transaction	$ 1,500,000,000

Equity (Earnings Per Share) (De

Equity (Earnings Per Share) (Details) $ / shares in Units, $ in Millions		12 Months Ended
	Sep. 14, 2020 shares	Dec. 31, 2022 USD ($) $ / shares shares	Dec. 31, 2021 USD ($) $ / shares shares	Dec. 31, 2020 USD ($) $ / shares shares	Oct. 26, 2020 shares
Reconciliation of basic and diluted earnings per share of common stock [Abstract]
Net income (loss) attributable to NEE | $		$ 4,147	$ 3,573	$ 2,919
Denominator:
Weighted-average number of common shares outstanding – basic		1,972,600,000	1,962,500,000	1,959,000,000
Equity units, stock options, performance share awards, forward sale agreements and restricted stock		6,000,000	9,700,000	9,800,000
Weighted-average number of common shares outstanding – assuming dilution		1,978,600,000	1,972,200,000	1,968,800,000
Earnings per share attributable to NEE:
Basic | $ / shares		$ 2.10	$ 1.82	$ 1.49
Assuming dilution | $ / shares		$ 2.10	$ 1.81	$ 1.48
Antidilutive securities (in shares)		38,100,000	30,500,000	27,100,000
Stockholders' Equity Note, Stock Split, Conversion Ratio	4
Common stock, authorized (in shares)	800,000,000	3,200,000,000	3,200,000,000		3,200,000,000

Equity (Issuance of Stock and F

Equity (Issuance of Stock and Forward Sale Agreement) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Jun. 30, 2021	Dec. 31, 2020
NEP [Member]
Class of Stock [Line Items]
Senior unsecured convertible notes outstanding	$ 500	$ 500	$ 600

Equity (Stock-Based Compensatio

Equity (Stock-Based Compensation) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Stock-based compensation
Stock based compensation costs	$ 142	$ 119	$ 107
Tax benefits related to stock-based compensation arrangements	20	$ 19	$ 21
Unrecognized stock based compensation costs	$ 160
Unrecognized stock based compensation costs weighted-average period of recognition (in years)	2 years 6 months
Common stock authorized for awards (in shares)	81,000,000
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, 2022	Dec. 31, 2021	Dec. 31, 2020
Restricted Stock Awards [Member]
Activity [Roll Forward]
Nonvested balance at beginning of year (in shares)	1,817,732
Granted (in shares)	1,001,259
Vested (in shares)	(758,006)
Forfeited (in shares)	(68,940)
Nonvested balance at end of year (in shares)	1,992,045	1,817,732
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)	$ 68.09
Granted, weighted-average grant date fair value (in dollars per share)	75.13	$ 82.69	$ 68.25
Vested, weighted-average grant date fair value (in dollars per share)	58.83
Forfeited, weighted-average grant date fair value (in dollars per share)	76.65
Nonvested balance at end of year, weighted-average grant date fair value (in dollars per share)	$ 77.93	$ 68.09
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Award vesting period	3 years
Performance Share Awards [Member]
Activity [Roll Forward]
Nonvested balance at beginning of year (in shares)	1,412,149
Granted (in shares)	1,597,586
Vested (in shares)	(1,563,850)
Forfeited (in shares)	(308,803)
Nonvested balance at end of year (in shares)	1,137,082	1,412,149
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)	$ 61.22
Granted, weighted-average grant date fair value (in dollars per share)	58.67	$ 54.82	$ 46.09
Vested, weighted-average grant date fair value (in dollars per share)	56.08
Forfeited, weighted-average grant date fair value (in dollars per share)	74.01
Nonvested balance at end of year, weighted-average grant date fair value (in dollars per share)	$ 71.17	$ 61.22
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	$ 175	$ 186	$ 177
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, 2022	Dec. 31, 2021	Dec. 31, 2020
Assumptions used to estimate the fair value of options using the Black-Scholes option pricing model [Abstract]
Expected term (years)	6 years 6 months	7 years	7 years
Option activity [Roll Forward]
Shares underlying options - Balance at beginning of year (in shares)	10,013,312
Shares underlying options - Granted (in shares)	1,304,270
Shares underlying options - Exercised (in shares)	(594,220)
Shares underlying options - forfeited (in shares)	23,952
Shares underlying options - Balance at end of year (in shares)	10,699,410	10,013,312
Shares underlying options - Exercisable (in shares)	8,152,185
Additional disclosures pertaining to options [Abstract]
Balance at beginning of year, weighted average exercise price (in dollars per share)	$ 44.87
Granted, weighted average exercise price (in dollars per share)	75.28
Exercised, weighted average exercise price (in dollars per share)	23.77
Forfeited, weighted average exercise price (in dollars per share)	78.33
Balance at end of year, weighted average exercise price (in dollars per share)	49.67	$ 44.87
Exercisable at end of year, weighted average exercise price (in dollars per share)	$ 41.28
Balance at end of year, weighted average remaining contractual term (years)	5 years 8 months 12 days
Exercisable at end of year, weighted average remaining contractual term (years)	4 years 9 months 18 days
Balance at end of year, aggregate intrinsic value	$ 363
Exercisable at end of year, aggregate intrinsic value	$ 345
Granted, weighted average grant date fair value (in dollars per share)	$ 10.49	$ 9.82	$ 7.08
Total intrinsic value of stock options exercised	$ 37,000,000	$ 49,000,000	$ 71,000,000
Cash received from option exercises	14,000,000	15,000,000	30,000,000
Tax benefit realized from options exercised	$ 9,000,000	$ 11,000,000	$ 17,000,000
Minimum [Member]
Assumptions used to estimate the fair value of options using the Black-Scholes option pricing model [Abstract]
Expected volatility (in hundredths)	17.91%	17.32%	14.63%
Expected dividends (in hundredths)	2.32%	2.30%	2.50%
Risk-free rate (in hundredths)	1.91%	0.80%	0.49%
Maximum [Member]
Assumptions used to estimate the fair value of options using the Black-Scholes option pricing model [Abstract]
Expected volatility (in hundredths)	19.37%	17.75%	16.31%
Expected dividends (in hundredths)	2.50%	2.44%	2.72%
Risk-free rate (in hundredths)	3.85%	1.27%	1.52%

Equity (Additional Disclosures

Equity (Additional Disclosures Regarding Common and Preferred Stock) (Details)	Dec. 31, 2022 $ / shares shares
NextEra Energy [Member] | Serial Preferred Stock [Member]
Preferred stock [Abstract]
Authorized (in shares)	100,000,000
Par value (in dollars per share) | $ / shares	$ 0.01
Preferred Stock Number Of Shares Outstanding	0
FPL [Member] | Preferred Stock, $100 Par Value [Member]
Preferred stock [Abstract]
Authorized (in shares)	10,414,100
Par value (in dollars per share) | $ / shares	$ 100
FPL [Member] | Preferred Stock, No Par Value [Member]
Preferred stock [Abstract]
Authorized (in shares)	5,000,000
Par value (in dollars per share) | $ / shares	$ 0
FPL [Member] | Subordinated Preferred Stock [Member] | Preferred Stock, No Par Value [Member]
Preferred stock [Abstract]
Authorized (in shares)	5,000,000
Par value (in dollars per share) | $ / shares	$ 0
Preferred Stock Number Of Shares Outstanding	0

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss), beginning	$ 0	$ (92)	$ (169)
Other comprehensive income (loss), before reclassifications	(260)	84	63
Amounts reclassified from AOCI	23	7	11
Total other comprehensive income (loss), net of tax	(237)	91	74
Less other comprehensive (income) loss attributable to noncontrolling interests	19	1	(7)
AOCI Impact of Disposal of a Business			10
Accumulated other comprehensive income (loss), ending	(218)	0	(92)
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	(14)
Net Unrealized Gains (Losses) on Cash Flow Hedges
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss), beginning	14	8	(27)
Other comprehensive income (loss), before reclassifications	0	0	0
Amounts reclassified from AOCI	6	6	12
Total other comprehensive income (loss), net of tax	6	6	12
Less other comprehensive (income) loss attributable to noncontrolling interests	0	0	0
AOCI Impact of Disposal of a Business			23
Accumulated other comprehensive income (loss), ending	20	14	8
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	0
Net Unrealized Gains (Losses) on Available for Sale Securities
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss), beginning	5	20	11
Other comprehensive income (loss), before reclassifications	(84)	(11)	12
Amounts reclassified from AOCI	10	(4)	(3)
Total other comprehensive income (loss), net of tax	(74)	(15)	9
Less other comprehensive (income) loss attributable to noncontrolling interests	0	0	0
AOCI Impact of Disposal of a Business			0
Accumulated other comprehensive income (loss), ending	(69)	5	20
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	0
Defined Benefit Pension and Other Benefits Plans
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss), beginning	25	(75)	(114)
Other comprehensive income (loss), before reclassifications	(133)	95	37
Amounts reclassified from AOCI	7	5	2
Total other comprehensive income (loss), net of tax	(126)	100	39
Less other comprehensive (income) loss attributable to noncontrolling interests	0	0	0
AOCI Impact of Disposal of a Business			0
Accumulated other comprehensive income (loss), ending	(101)	25	(75)
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	0
Net Unrealized Gains (Losses) on Foreign Currency Translation
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss), beginning	(49)	(49)	(42)
Other comprehensive income (loss), before reclassifications	(44)	(1)	13
Amounts reclassified from AOCI	0	0	0
Total other comprehensive income (loss), net of tax	(44)	(1)	13
Less other comprehensive (income) loss attributable to noncontrolling interests	19	1	(7)
AOCI Impact of Disposal of a Business			(13)
Accumulated other comprehensive income (loss), ending	(74)	(49)	(49)
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	(14)
Other Comprehensive Income Related to Equity Method Investees
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss), beginning	5	4	3
Other comprehensive income (loss), before reclassifications	1	1	1
Amounts reclassified from AOCI	0	0	0
Total other comprehensive income (loss), net of tax	1	1	1
Less other comprehensive (income) loss attributable to noncontrolling interests	0	0	0
AOCI Impact of Disposal of a Business			0
Accumulated other comprehensive income (loss), ending	6	$ 5	$ 4
AOCI Including Portion Attributable to Noncontrolling Interest, Net Of Tax	$ 0

Commitments and Contingencies_2

Commitments and Contingencies (Estimated Planned Capital Expenditures) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($) MW
Planned Capital Expenditures [Line Items]
Guarantor Obligations, Current Carrying Value	$ 495
NEER Segment
Planned Capital Expenditures [Line Items]
2023	8,875
2024	3,050
2025	880
2026	480
2027	420
Total	13,705
Wind Expenditures [Member] | NEER Segment
Planned Capital Expenditures [Line Items]
2023	2,650
2024	1,095
2025	315
2026	20
2027	20
Total	$ 4,100
Planned New Generation To Be Added over 5 Years | MW	2,955
Solar Expenditures [Member] | NEER Segment
Planned Capital Expenditures [Line Items]
2023	$ 4,020
2024	1,145
2025	225
2026	0
2027	0
Total	$ 5,390
Planned New Generation To Be Added over 5 Years | MW	6,618
Other Clean Energy Expenditures [Member] | NEER Segment
Planned Capital Expenditures [Line Items]
2023	$ 1,175
2024	350
2025	55
2026	75
2027	45
Total	1,700
Nuclear Expenditures [Member] | NEER Segment
Planned Capital Expenditures [Line Items]
2023	95
2024	215
2025	145
2026	260
2027	285
Total	1,000
Rate-Regulated Transmission [Member] | NEER Segment
Planned Capital Expenditures [Line Items]
2023	170
2024	65
2025	45
2026	10
2027	10
Total	300
Other Expenditures [Member] | NEER Segment
Planned Capital Expenditures [Line Items]
2023	765
2024	180
2025	95
2026	115
2027	60
Total	1,215
FPL [Member]
Planned Capital Expenditures [Line Items]
2023	9,020
2024	8,080
2025	8,225
2026	8,875
2027	8,940
Total	43,140
FPL [Member] | New Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
2023	3,060
2024	2,315
2025	2,820
2026	3,670
2027	3,150
Total	15,015
FPL [Member] | Existing Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
2023	1,615
2024	1,175
2025	1,045
2026	1,280
2027	1,465
Total	6,580
FPL [Member] | Transmission and Distribution Expenditures [Member]
Planned Capital Expenditures [Line Items]
2023	3,545
2024	3,975
2025	3,645
2026	3,340
2027	3,575
Total	18,080
Planned Generation Capital Expenditures AFUDC First Year	60
Planned Generation Capital Expenditures AFUDC Second Year	50
Planned Generation Capital Expenditures AFUDC Third Year	55
Planned Generation Capital Expenditures AFUDC Fourth Year	30
Planned Generation Capital Expenditures AFUDC Fifth Year	30
FPL [Member] | Nuclear Fuel Expenditures [Member]
Planned Capital Expenditures [Line Items]
2023	125
2024	160
2025	200
2026	200
2027	225
Total	910
FPL [Member] | General and Other Expenditures [Member]
Planned Capital Expenditures [Line Items]
2023	675
2024	455
2025	515
2026	385
2027	525
Total	2,555
FPL [Member] | Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
Planned Generation Capital Expenditures AFUDC First Year	105
Planned Generation Capital Expenditures AFUDC Second Year	105
Planned Generation Capital Expenditures AFUDC Third Year	90
Planned Generation Capital Expenditures AFUDC Fourth Year	125
Planned Generation Capital Expenditures AFUDC Fifth Year	$ 115

Commitments and Contingencies_3

Commitments and Contingencies (Required Capacity and/or Minimum Payments Under Contracts) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
NEER Segment
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2023	$ 2,995
Capacity payments and/or minimum payments - 2024	1,145
Capacity payments and/or minimum payments - 2025	135
Capacity payments and/or minimum payments - 2026	90
Capacity payments and/or minimum payments - 2027	80
Capacity payments and/or minimum payments - Thereafter	510
Commitment to invest	260
Joint Obligations First Year	205
Joint Obligations Second Year	865
Joint Obligations Third Year	5
Joint Obligations Fourth Year	5
Joint Obligations Fifth Year	0
Joint ObligationsThereafter	$ 0
Mountain Valley Pipeline [Member] | NEER Segment
Long-term Purchase Commitment [Line Items]
Natural gas transportation agreement, term	20 years
Amounts Excluded from Required Capacity and or Minimum Payments, Annual Commitment	$ 70
Contract Group 1 [Member] | NEER Segment
Long-term Purchase Commitment [Line Items]
Commitment amount included in capital expenditures	3,700
FPL [Member]
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2023	1,040
Capacity payments and/or minimum payments - 2024	970
Capacity payments and/or minimum payments - 2025	940
Capacity payments and/or minimum payments - 2026	930
Capacity payments and/or minimum payments - 2027	850
Capacity payments and/or minimum payments - Thereafter	8,075
Related Party Transaction, Amounts of Transaction	418	$ 419	$ 386
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 - 2023	410
Capacity payments and/or minimum payments - 2024	410
Capacity payments and/or minimum payments - 2025	405
Capacity payments and/or minimum payments - 2026	400
Capacity payments and/or minimum payments - 2027	400
Capacity payments and/or minimum payments - Thereafter	$ 5,560
Join Venture [Member] | NEER Segment
Long-term Purchase Commitment [Line Items]
Ownership interest	32.20%
Consolidation, Eliminations [Member] | FPL [Member]
Long-term Purchase Commitment [Line Items]
Related Party Transaction, Amounts of Transaction	$ 102	$ 105	$ 108

Commitments and Contingencies_4

Commitments and Contingencies (Insurance) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($)
Insurance [Abstract]
Maximum obtainable amount of private liability insurance available under Price-Anderson Act	$ 450
Amount of secondary financial protection liability insurance coverage per incident	13,200
Potential retrospective assessments under secondary financial protection system	963
Potential retrospective assessments under secondary financial protection system payable per incident per year	143
Amount of coverage per occurrence per site for property damage, decontamination and premature decommissioning risks	2,750
Amount of sublimit for non nuclear perils per occurrence per site under nuclear insurance mutual companies for property damage decontamination and premature decommissioning risks	$ 1,500
Coinsurance, percent	10%
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	158
Seabrook Station Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for nuclear liability secondary financial protection	16
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	2
Duane Arnold Energy Center Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	2
St Lucie Unit No 2 Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for nuclear liability secondary financial protection	20
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	4
FPL [Member]
Insurance [Abstract]
Potential retrospective assessments under secondary financial protection system	550
Potential retrospective assessments under secondary financial protection system payable per incident per year	82
Potential retrospective assessment, limited insurance coverage per occurrence per site, nuclear insurance mutual companies, property damage decontamination and premature decommissioning risks	101
Duane Arnold Energy Center Insurance [Member]
Insurance [Abstract]
Maximum obtainable amount of private liability insurance available under Price-Anderson Act	100
Amount of sublimit for non nuclear perils per occurrence per site under nuclear insurance mutual companies for property damage decontamination and premature decommissioning risks	$ 50

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Operating revenue		$ 20,956	$ 17,069	$ 17,997
Operating expenses - net		17,397	14,233	13,234
Gains (losses) on disposal of businesses/assets – net		522	77	353
Interest expense		585	1,270	1,950
Depreciation and amortization		4,503	3,924	4,052
Equity in earnings (losses) of equity method investees		203	666	(1,351)
Income Tax Expense (Benefit)		586	348	44
Net income (loss)		3,246	2,827	2,369
NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS		901	746	550
Net income (loss) attributable to NEE		4,147	3,573	2,919
Capital expenditures, independent power and other investments and nuclear fuel purchases		19,283	16,077	14,610
Property, plant and equipment – net		111,059	99,348	91,803
Total assets		158,935	140,912	127,684
Investment in equity method investees		6,582	6,159	5,728
Retained Earnings [Member]
Segment Reporting Information [Line Items]
Net income (loss)		4,147	3,573	2,919
FPL [Member]
Segment Reporting Information [Line Items]
Operating revenue		17,282	14,102	13,060
Operating expenses - net		11,988	9,586	8,940
Interest expense		768	615	641
Depreciation and amortization		2,695	2,266	2,526
Income Tax Expense (Benefit)		947	838	678
Net income (loss)		3,701	3,206	2,890	[1]
Electric utility plant and other property – net		64,693	58,227
Total assets		86,559	78,067
FPL [Member] | Retained Earnings [Member]
Segment Reporting Information [Line Items]
Net income (loss)	[1]	3,701	3,206
Net income (loss) attributable to NEE		$ 3,701	$ 3,206	$ 2,890
NEER [Member]
Segment Reporting Information [Line Items]
Deemed Capital Structure		70%	70%	70%
Operating Segments [Member] | FPL [Member]
Segment Reporting Information [Line Items]
Operating revenue		$ 17,282	$ 14,102	$ 13,060
Operating expenses - net		11,992	9,587	8,940
Gains (losses) on disposal of businesses/assets – net		4	1	0
Interest expense		768	615	641
Depreciation and amortization		2,695	2,266	2,526
Equity in earnings (losses) of equity method investees		0	0	0
Income Tax Expense (Benefit)		947	838	678
Net income (loss)		3,701	3,206	2,890
NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS		0	0	0
Net income (loss) attributable to NEE		3,701	3,206	2,890
Capital expenditures, independent power and other investments and nuclear fuel purchases		9,185	7,570	7,679
Electric utility plant and other property – net		64,693	58,227	53,879
Total assets		86,559	78,067	71,001
Investment in equity method investees		0	0	0
Operating Segments [Member] | NEER Segment
Segment Reporting Information [Line Items]
Operating revenue		3,720	3,053	5,046
Operating expenses - net		5,140	4,434	4,125
Gains (losses) on disposal of businesses/assets – net		536	78	363
Interest expense		128	367	659
Depreciation and amortization		1,722	1,576	1,460
Equity in earnings (losses) of equity method investees		202	666	(1,351)
Income Tax Expense (Benefit)		(391)	(395)	(416)
Net income (loss)		(616)	(147)	(19)
NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS		901	746	550
Net income (loss) attributable to NEE		285	599	531
Capital expenditures, independent power and other investments and nuclear fuel purchases		9,645	8,363	6,893
Property, plant and equipment – net		45,840	40,900	37,842
Total assets		70,713	62,113	55,633
Investment in equity method investees		6,572	6,150	5,713
Corporate And Eliminations
Segment Reporting Information [Line Items]
Operating revenue		(46)	(86)	(109)
Operating expenses - net		265	212	169
Gains (losses) on disposal of businesses/assets – net		(18)	(2)	(10)
Interest expense		(311)	288	650
Depreciation and amortization		86	82	66
Equity in earnings (losses) of equity method investees		1	0	0
Income Tax Expense (Benefit)		30	(95)	(218)
Net income (loss)		161	(232)	(502)
NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS		0	0	0
Net income (loss) attributable to NEE		161	(232)	(502)
Capital expenditures, independent power and other investments and nuclear fuel purchases		453	144	38
Property, plant and equipment – net		526	221	82
Total assets		1,663	732	1,050
Investment in equity method investees		$ 10	$ 9	$ 15
[1]FPL's comprehensive income is the same as reported net income.