Florida Power & Light 10-K 23 Feb 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2016	Jan. 31, 2017	Jun. 30, 2016
Entity Information [Line Items]
Entity Registrant Name	NEXTERA ENERGY INC
Entity Central Index Key	753,308
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 60,089,366,330
Entity Common Stock, Shares Outstanding		467,581,899
FPL [Member]
Entity Information [Line Items]
Entity Registrant Name	FLORIDA POWER & LIGHT CO
Entity Central Index Key	37,634
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Common Stock, Shares Outstanding		1,000

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
OPERATING REVENUES		$ 16,155	$ 17,486	$ 17,021
OPERATING EXPENSES (INCOME)
Fuel, purchased power and interchange		4,042	5,327	5,602
Other operations and maintenance		3,389	3,269	3,149
Merger-related		135	26	0
Depreciation and amortization		3,077	2,831	2,551
Losses (gains) on disposal of assets - net		(446)	4	(27)
Taxes other than income taxes and other - net		1,350	1,397	1,362
Total operating expenses - net		11,547	12,854	12,637
OPERATING INCOME		4,608	4,632	4,384
OTHER INCOME (DEDUCTIONS)
Interest expense		(1,093)	(1,211)	(1,261)
Benefits associated with differential membership interests - net		309	216	199
Equity in earnings of equity method investees		148	107	93
Allowance for equity funds used during construction		86	70	37
Interest income		82	86	80
Gains on disposal of investments and other property - net		40	90	105
Gain associated with Maine fossil		0	0	21
Other than temporary impairment losses on securities held in nuclear decommissioning funds		(23)	(40)	(13)
Revaluation of contingent consideration		189	0	0
Other - net		42	40	0
Total other deductions - net		(220)	(642)	(739)
INCOME (LOSS) BEFORE INCOME TAXES		4,388	3,990	3,645
INCOME TAXES		1,383	1,228	1,176
NET INCOME		3,005	2,762	2,469
LESS NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS		93	10	4
Net income attributable to parent		$ 2,912	$ 2,752	$ 2,465
Earnings per share attributable to NEE:
Basic EPS - Continuing operations		$ 6.29	$ 6.11	$ 5.67
Earnings per share attributable to NEE - assuming dilution:
Diluted EPS - Continuing operations		$ 6.25	$ 6.06	$ 5.60
Weighted-average number of common shares outstanding:
Basic		463.1	450.5	434.4
Assuming dilution		465.8	454	440.1
FPL [Member]
OPERATING REVENUES		$ 10,895	$ 11,651	$ 11,421
OPERATING EXPENSES (INCOME)
Fuel, purchased power and interchange		3,297	4,276	4,375
Other operations and maintenance		1,600	1,617	1,620
Depreciation and amortization		1,651	1,576	1,432
Taxes other than income taxes and other - net		1,189	1,205	1,166
Total operating expenses - net		7,737	8,674	8,593
OPERATING INCOME		3,158	2,977	2,828
OTHER INCOME (DEDUCTIONS)
Interest expense		(456)	(445)	(439)
Allowance for equity funds used during construction		74	68	36
Other - net		2	5	2
Total other deductions - net		(380)	(372)	(401)
INCOME (LOSS) BEFORE INCOME TAXES		2,778	2,605	2,427
INCOME TAXES		1,051	957	910
Net income attributable to parent	[1]	$ 1,727	$ 1,648	$ 1,517
[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, 2016	Dec. 31, 2015	Dec. 31, 2014
Net income	$ 3,005	$ 2,762	$ 2,469
Effective portion of net unrealized losses (net of $37 and $80 tax benefit, respectively)	0	(88)	(141)
Reclassification from accumulated other comprehensive income to net income (net of $32, $25 and $57 tax expense, respectively)	70	63	98
Net unrealized gains (losses) on securities still held (net of $50 tax expense, $8 tax benefit and $45 tax expense, respectively)	69	(7)	62
Reclassification from accumulated other comprehensive income to net income (net of $13, $33 and $26 tax benefit, respectively)	(18)	(37)	(41)
Defined benefit pension and other benefits plans (net of $13, $26 and $27 tax benefit, respectively)	(21)	(42)	(43)
Net unrealized losses on foreign currency translation (net of $2, $2 and $12 tax benefit, respectively)	(5)	(27)	(25)
Other comprehensive income (loss) related to equity method investee (net of $2 tax expense and $5 tax benefit, respectively)	2	0	(8)
Total other comprehensive income (loss), net of tax	97	(138)	(98)
COMPREHENSIVE INCOME	3,102	2,624	2,371
LESS COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO NONCONTROLLING INTERESTS	93	(1)	2
COMPREHENSIVE INCOME ATTRIBUTABLE TO NEE	$ 3,009	$ 2,625	$ 2,369

CONSOLIDATED STATEMENTS OF COM4

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash Flow Hedges - Effective portion of net unrealized gains (tax (benefit) expense)	$ 0	$ (37)	$ (80)
Cash Flow Hedges - Reclassification from AOCI to net income (tax (benefit) expense)	32	25	57
Available for Sale - Net unrealized gains on securities still held (tax (benefit) expense)	50	(8)	45
Available for Sale - Reclassification from AOCI to net income (tax (benefit) expense)	(13)	(33)	(26)
Defined benefit pension and other benefits plans (tax (benefit) expense)	(13)	(26)	(27)
Net unrealized gains on foreign currency translation (tax (benefit) expense)	(2)	(2)	(12)
Other comprehensive income (loss) related to equity method investee, tax	$ 2	$ 0	$ (5)

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	$ 80,150	$ 72,606
Nuclear fuel	2,131	2,067
Construction work in progress	4,732	5,657
Accumulated depreciation and amortization	(20,101)	(18,944)
Total property, plant and equipment - net	66,912	61,386
CURRENT ASSETS
Cash and cash equivalents	1,292	571
Customer receivables, net of allowances	1,784	1,784
Other receivables	655	481
Materials, supplies and fossil fuel inventory	1,289	1,259
Regulatory assets	524	503
Derivatives	885	712
Assets held for sale	452	1,009
Other	528	476
Total current assets	7,409	6,795
OTHER ASSETS
Special use funds	5,434	5,138
Other investments ($479 related to a VIE at December 31, 2016)	2,482	1,786
Prepaid benefit costs	1,177	1,155
Regulatory assets ($107 and $128 related to a VIE, respectively)	1,894	1,778
Derivatives	1,350	1,202
Other	3,335	3,239
Total other assets	15,672	14,298
TOTAL ASSETS	89,993	82,479
CAPITALIZATION
Common stock	5	5
Additional paid-in capital	8,948	8,596
Retained earnings	15,458	14,140
Accumulated other comprehensive loss	(70)	(167)
Total common shareholders' equity	24,341	22,574
Noncontrolling interests	990	538
Total equity	25,331	23,112
Long-term debt	27,818	26,681
Total capitalization	53,149	49,793
CURRENT LIABILITIES
Commercial paper	268	374
Other short-term debt	150	412
Current maturities of long-term debt	2,604	2,220
Accounts payable	3,447	2,529
Customer deposits	470	473
Accrued interest and taxes	480	449
Derivatives	404	882
Accrued construction-related expenditures	1,120	921
Regulatory liabilities	299	14
Liabilities associated with assets held for sale	451	992
Other	1,226	841
Total current liabilities	10,919	10,107
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	2,736	2,469
Deferred income taxes	11,101	9,827
Regulatory liabilities	4,906	4,606
Derivatives	477	530
Deferral related to differential membership interests - VIEs	4,656	3,142
Other	2,049	2,005
Total other liabilities and deferred credits	25,925	22,579
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	89,993	82,479
FPL [Member]
ELECTRIC UTILITY PLANT AND OTHER PROPERTY
Plant in service and other property	44,966	41,227
Nuclear fuel	1,308	1,306
Construction work in progress	2,039	2,850
Accumulated depreciation and amortization	(12,304)	(11,862)
Total electric utility plant and other property - net	36,009	33,521
CURRENT ASSETS
Cash and cash equivalents	33	23
Customer receivables, net of allowances	768	849
Other receivables	148	123
Materials, supplies and fossil fuel inventory	851	826
Regulatory assets	524	502
Derivatives	209	3
Other	213	181
Total current assets	2,746	2,507
OTHER ASSETS
Special use funds	3,665	3,504
Prepaid benefit costs	1,301	1,243
Regulatory assets ($107 and $128 related to a VIE, respectively)	1,573	1,513
Other	207	235
Total other assets	6,746	6,495
TOTAL ASSETS	45,501	42,523
CAPITALIZATION
Common stock	1,373	1,373
Additional paid-in capital	8,332	7,733
Retained earnings	6,875	6,447
Total common shareholders' equity	16,580	15,553
Total equity	16,580	15,553
Long-term debt	9,705	9,956
Total capitalization	26,285	25,509
CURRENT LIABILITIES
Commercial paper	268	56
Other short-term debt	150	100
Current maturities of long-term debt	367	64
Accounts payable	837	664
Customer deposits	466	469
Accrued interest and taxes	240	279
Derivatives	1	222
Accrued construction-related expenditures	262	240
Regulatory liabilities	294	12
Other	496	343
Total current liabilities	3,381	2,449
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,919	1,822
Deferred income taxes	8,541	7,730
Regulatory liabilities	4,893	4,595
Other	482	418
Total other liabilities and deferred credits	15,835	14,565
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$ 45,501	$ 42,523

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Total property, plant and equipment - net	$ 66,912	$ 61,386
Customer receivables, net of allowances	5	13
Other investments ($479 related to a VIE at December 31, 2016)	2,482	1,786
Regulatory assets ($107 and $128 related to a VIE, respectively)	$ 1,894	$ 1,778
Common stock, par value	$ 0.01	$ 0.01
Common stock, authorized (in shares)	800,000,000	800,000,000
Common stock, outstanding (in shares)	468,000,000	461,000,000
Long-term debt	$ 27,818	$ 26,681
Related to VIEs [Member]
Total property, plant and equipment - net	14,632	7,966
Other investments ($479 related to a VIE at December 31, 2016)	479	0
Regulatory assets ($107 and $128 related to a VIE, respectively)	107	128
Long-term debt	5,080	684
FPL [Member]
Customer receivables, net of allowances	3	2
Regulatory assets ($107 and $128 related to a VIE, respectively)	$ 1,573	$ 1,513
Common stock, authorized (in shares)	1,000	1,000
Common stock, par value	$ 0	$ 0
Common stock, issued (in shares)	1,000	1,000
Common stock, outstanding (in shares)	1,000	1,000
Long-term debt	$ 9,705	$ 9,956
FPL [Member] | Related to VIEs [Member]
Regulatory assets ($107 and $128 related to a VIE, respectively)	107	128
Long-term debt	$ 144	$ 210

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
CASH FLOWS FROM OPERATING ACTIVITIES
Net income		$ 3,005	$ 2,762	$ 2,469
NET INCOME		2,912	2,752	2,465
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization		3,077	2,831	2,551
Nuclear fuel and other amortization		300	372	345
Unrealized gains on marked to market derivative contracts - net		(44)	(337)	(411)
Foreign currency transaction losses		13	0	0
Deferred income taxes		1,230	1,162	1,205
Cost recovery clauses and franchise fees		94	176	(67)
Purchased power agreement termination		0	(521)	0
Benefits associated with differential membership interests - net		(309)	(216)	(199)
Gains on disposal of assets - net		(490)	(89)	(133)
Recoverable storm-related costs		(223)	0	0
Other - net		(94)	68	278
Changes in operating assets and liabilities:
Current assets		(120)	73	(172)
Noncurrent assets		(67)	(106)	(220)
Current liabilities		(24)	64	(134)
Noncurrent liabilities		(12)	(123)	(12)
Net cash provided by operating activities		6,336	6,116	5,500
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL		(3,776)	(3,428)	(3,067)
Independent power and other investments of NEER		(5,396)	(4,505)	(3,588)
Cash grants under the American Recovery and Reinvestment Act of 2009		335	8	343
Nuclear fuel purchases		(283)	(361)	(287)
Other capital expenditures and other investments		(181)	(83)	(75)
Sale of independent power and other investments of NEER		658	52	307
Proceeds from sale or maturity of securities in special use funds and other investments		3,776	4,851	4,621
Purchases of securities in special use funds and other investments		(3,829)	(4,982)	(4,767)
Proceeds from the sale of a noncontrolling interest in subsidiaries		645	345	438
Other - net		(59)	98	(286)
Net cash used in investing activities		(8,110)	(8,005)	(6,361)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt		5,657	5,772	5,054
Retirements of long-term debt		(3,310)	(3,972)	(4,750)
Proceeds from differential membership investors		1,859	761	978
Payments to differential membership investors		(122)	(92)	(71)
Proceeds from other short-term debt		500	1,225	500
Repayments of other short-term debt		(662)	(813)	(500)
Net change in commercial paper		(106)	(768)	451
Issuances of common stock - net		537	1,298	633
Dividends on common stock		(1,612)	(1,385)	(1,261)
Other - net		(246)	(143)	(34)
Net cash provided by (used in) financing activities		2,495	1,883	1,000
Net increase (decrease) in cash and cash equivalents		721	(6)	139
Cash and cash equivalents at beginning of year		571	577	438
Cash and cash equivalents at end of year		1,292	571	577
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)		1,193	1,143	1,181
Cash paid for income taxes - net		91	33	46
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions		3,626	2,616	956
Assumption of debt/acquisition holdbacks in connection with Texas pipeline acquisition		0	1,078	0
Decrease in property, plant and equipment - net as a result of cash grants under the American Recovery and Reinvestment Act of 2009		419	224	161
Decrease (increase) in property, plant and equipment as a result of a settlement		(72)	(45)	181
Proceeds from differential membership investors used to reduce debt		100	0	0
FPL [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
NET INCOME	[1]	1,727	1,648	1,517
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization		1,651	1,576	1,432
Nuclear fuel and other amortization		218	209	201
Deferred income taxes		932	504	601
Cost recovery clauses and franchise fees		94	176	(67)
Purchased power agreement termination		0	(521)	0
Recoverable storm-related costs		(223)	0	0
Other - net		42	(56)	94
Changes in operating assets and liabilities:
Current assets		26	(89)	(125)
Noncurrent assets		(31)	(53)	(103)
Current liabilities		16	40	(70)
Noncurrent liabilities		(86)	(41)	(26)
Net cash provided by operating activities		4,366	3,393	3,454
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL		(3,776)	(3,428)	(3,067)
Nuclear fuel purchases		(158)	(205)	(174)
Proceeds from sale or maturity of securities in special use funds and other investments		2,495	3,731	3,349
Purchases of securities in special use funds and other investments		(2,506)	(3,792)	(3,414)
Other - net		(15)	19	(268)
Net cash used in investing activities		(3,960)	(3,675)	(3,574)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt		309	1,084	997
Retirements of long-term debt		(262)	(551)	(355)
Proceeds from other short-term debt		500	100	0
Repayments of other short-term debt		(450)	0	0
Net change in commercial paper		212	(1,086)	938
Capital contributions from NEE		600	1,454	100
Dividends on common stock		(1,300)	(700)	(1,550)
Other - net		(5)	(10)	(15)
Net cash provided by (used in) financing activities		(396)	291	115
Net increase (decrease) in cash and cash equivalents		10	9	(5)
Cash and cash equivalents at beginning of year		23	14	19
Cash and cash equivalents at end of year		33	23	14
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)		434	435	417
Cash paid for income taxes - net		147	439	342
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions		$ 664	$ 474	$ 404
[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]	Unearned ESOP Compensation [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Retained Earnings [Member]	Total common Shareholders' Equity [Member]	Noncontrolling Interest [Member]	FPL [Member]		FPL [Member]Common Stock [Member]	FPL [Member]Additional Paid-in Capital [Member]	FPL [Member]Retained Earnings [Member]
Balances (in shares) at Dec. 31, 2013			435,000,000
Beginning Balance at Dec. 31, 2013		$ 18,040	$ 4	$ 6,437	$ (26)	$ 56	$ 11,569	$ 18,040	$ 0
BEGINNING BALANCE at Dec. 31, 2013										$ 13,084		$ 1,373	$ 6,179	$ 5,532
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		2,469					2,465	2,465	4
NET INCOME		2,465								1,517	[1]			1,517
Issuances of common stock, net of issuance cost of less than $1				604	3			607
Issuances of common stock, net of issuance cost (in shares)			7,000,000
Exercise of stock options and other incentive plan activity				102				102
Exercise of stock options and other incentive plan activity (in shares)			1,000,000
Dividends on common stock	[2]						(1,261)	(1,261)
Other comprehensive income (loss)		(98)				(96)		(96)	(2)
NEP acquisition of limited partner interest in NEP OpCo									232
Capital contributions from NEE										100			100
Dividends to NEE														(1,550)
Other				50	9			59	18
ENDING BALANCE at Dec. 31, 2014										13,151		1,373	6,279	5,499
Ending Balance at Dec. 31, 2014		20,168	$ 4	7,193	(14)	(40)	12,773	19,916	252
Balance (in shares) at Dec. 31, 2014			443,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		2,762					2,752	2,752	10
NET INCOME		2,752								1,648	[1]			1,648
Issuances of common stock, net of issuance cost of less than $1			$ 1	1,302	4			1,307
Issuances of common stock, net of issuance cost (in shares)			17,000,000
Dividends on common stock	[2]						(1,385)	(1,385)
Other comprehensive income (loss)		(138)				(127)		(127)	(11)
Premium on equity units				(80)				(80)
Sale of NEER Assets to NEP				88				88	252
Capital contributions from NEE										1,454			1,454
Dividends to NEE														(700)
Other (in shares)			1,000,000
Other				94	9			103	35
ENDING BALANCE at Dec. 31, 2015		22,574								15,553		1,373	7,733	6,447
Ending Balance at Dec. 31, 2015		$ 23,112	$ 5	8,597	(1)	(167)	14,140	22,574	538	$ 15,553
Balance (in shares) at Dec. 31, 2015		461,000,000	461,000,000							1,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		$ 3,005					2,912	2,912	93
NET INCOME		2,912								$ 1,727	[1]			1,727
Issuances of common stock, net of issuance cost of less than $1				527				527
Issuances of common stock, net of issuance cost (in shares)			6,000,000
Dividends on common stock	[2]						(1,612)	(1,612)
Other comprehensive income (loss)		97				97		97
Premium on equity units				(200)				(200)
Sale of NEER Assets to NEP				0					433
Capital contributions from NEE										600			600
Dividends to NEE														(1,300)
Other (in shares)			1,000,000
Other				24	1		18	43	(74)				(1)	1
ENDING BALANCE at Dec. 31, 2016		24,341								16,580		$ 1,373	$ 8,332	$ 6,875
Ending Balance at Dec. 31, 2016		$ 25,331	$ 5	$ 8,948	$ 0	$ (70)	$ 15,458	$ 24,341	$ 990	$ 16,580
Balance (in shares) at Dec. 31, 2016		468,000,000	468,000,000							1,000
[1]	FPL's comprehensive income is the same as reported net income
[2]	Dividends per share were $3.48, $3.08 and $2.90 for the years ended December 31, 2016, 2015 and 2014, respectively.

CONSOLIDATED STATEMENTS OF COM9

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement of Stockholders' Equity [Abstract]
Common stock issuance cost, less than	$ 1	$ 1	$ 1
Dividends per share of common stock (in dollars per share)	$ 3.48	$ 3.08	$ 2.90

Summary of Significant Accounti

Summary of Significant Accounting and Reporting Policies	12 Months Ended
	Dec. 31, 2016
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 (NEER), a wholly owned indirect subsidiary. FPL, a rate-regulated electric utility, supplies electric service to approximately 4.9 million customer accounts throughout most of the east and lower west coasts of Florida. NEER invests in independent power projects through both controlled and consolidated entities and noncontrolling ownership interests in joint ventures essentially all of which are accounted for under the equity method. NEER also participates in natural gas, natural gas liquids and oil production primarily through non-operating ownership interests and in pipeline infrastructure through either wholly owned subsidiaries or noncontrolling or joint venture interests. The consolidated financial statements of NEE and FPL include the accounts of their respective majority-owned and controlled subsidiaries. Intercompany balances and transactions have been eliminated in consolidation. Certain amounts included in prior years' consolidated financial statements have been reclassified to conform to the current year's presentation. The preparation of financial statements requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ from those estimates. NextEra Energy Partners, LP - NEE, through NEER, formed NextEra Energy Partners, LP (NEP) 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). On July 1, 2014, NEP closed its initial public offering (IPO) by issuing 18,687,500 common units representing limited partner interests. The proceeds from the sale of the common units, net of underwriting discounts, commissions and structuring fees, were approximately $ 438 million . NEP used such proceeds to purchase 18,687,500 common units of NEP OpCo, of which approximately $ 288 million was used to purchase common units from an indirect wholly owned subsidiary of NEE and $ 150 million was used to purchase common units from NEP OpCo. Through an indirect wholly owned subsidiary, NEE retained 74,440,000 units of NEP OpCo representing a 79.9% interest in NEP's operating projects. Additionally, NEE owns a controlling general partner interest in NEP and consolidates NEP for financial reporting purposes and presents NEP's limited partner interest as a noncontrolling interest in NEE's consolidated financial statements. Certain equity and asset transactions between NEP, NEER and NEP OpCo involve the exchange of cash, energy projects and ownership interests in NEP OpCo. These exchanges are accounted for under the profit sharing method and resulted in a profit sharing liability, net of amortization, of approximately $ 757 million and $ 447 million at December 31, 2016 and 2015 , respectively, which is reflected in noncurrent other liabilities on NEE's consolidated balance sheets. The profit sharing liability will be amortized into income on a straight-line basis over the estimated useful lives of the underlying energy projects held by NEP OpCo. Accordingly, the profit sharing liability amortization totaled approximately $ 37 million during 2016 and is included in taxes other than income taxes and other - net in NEE’s consolidated statements of income. During the purchase price adjustment period associated with the IPO, which ended in November 2016, approximately $288 million of the profit sharing liability was not amortized. During 2015 and 2016, NEP sold an additional 35,527,435 common units and purchased an additional 35,527,435 NEP OpCo common units. Also, in 2015, a subsidiary of NEE purchased 27,000,000 of NEP OpCo's common units. After giving effect to these transactions, NEE’s partnership interest in NEP OpCo's operating projects is approximately 65.2% as of December 31, 2016 . As of December 31, 2016 , NEP, through NEER's contribution of energy projects to NEP OpCo, owns or has an interest in a portfolio of 22 wind and solar projects with generating capacity totaling approximately 2,787 megawatts (MW), as well as a portfolio of seven long-term contracted natural gas pipeline assets located in Texas. In October 2015, NEE authorized a program to purchase, from time to time, up to $ 150 million of common units representing limited partner interests of NEP. Under the program, any purchases may be made in amounts, at prices and at such times as NEE or its subsidiaries deem appropriate, all subject to market conditions and other considerations. The common unit purchase program does not require NEE to acquire any specific number of common units and may be modified or terminated by NEE at any time. The purchases may be made in the open market or in privately negotiated transactions. As of December 31, 2016 , NEE had purchased approximately $ 36 million of NEP common units under this program. Rate Regulation - FPL is subject to rate regulation by the Florida Public Service Commission (FPSC) and the Federal Energy Regulatory Commission (FERC). Its rates are designed to recover the cost of providing electric 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, 2016 2015 2016 2015 (millions) Regulatory assets: Current: Derivatives $ — $ 218 $ — $ 218 Storm reserve deficiency 203 — 203 — Other 321 285 321 284 Total $ 524 $ 503 $ 524 $ 502 Noncurrent: Purchased power agreement termination $ 636 $ 726 $ 636 $ 726 Other 1,258 1,052 937 787 Total $ 1,894 $ 1,778 $ 1,573 $ 1,513 Regulatory liabilities: Current: Derivatives $ 208 $ — $ 208 $ — Other 91 14 86 12 Total $ 299 $ 14 $ 294 $ 12 Noncurrent: Accrued asset removal costs $ 1,956 $ 1,930 $ 1,944 $ 1,921 Asset retirement obligation regulatory expense difference 2,294 2,182 2,294 2,182 Other 656 494 655 492 Total $ 4,906 $ 4,606 $ 4,893 $ 4,595 Cost recovery clauses, which are designed to permit full recovery of certain costs and provide a return on certain assets allowed to be recovered through various clauses, include substantially all fuel, purchased power and interchange expense, certain costs associated with the acquisition of certain generation facilities, certain construction-related costs for certain of FPL's solar generation facilities, and conservation and certain environmental-related costs. Revenues from cost recovery clauses are recorded when billed; FPL achieves matching of costs and related revenues by deferring the net underrecovery or overrecovery. Any underrecovered costs or overrecovered revenues are collected from or returned to customers in subsequent periods. In 2015, FPL assumed ownership of a 250 MW coal-fired generation facility located in Jacksonville, Florida (Cedar Bay generation facility) and terminated its long-term purchased power agreement for substantially all of the facility’s capacity and energy for a purchase price of approximately $521 million . The FPSC approved a stipulation and settlement between the State of Florida Office of Public Counsel and FPL regarding issues relating to the ratemaking treatment for the Cedar Bay generation facility which provides for recovery of the purchase price and associated income tax gross-up as a regulatory asset of approximately $847 million which will be amortized over approximately nine years . At December 31, 2016 and 2015 , the regulatory assets, net of amortization, totaled approximately $726 million and $817 million , respectively, and are included in current and noncurrent regulatory assets on NEE’s and FPL’s consolidated balance sheets. This settlement also reduced the reserve amount that was available for amortization under the 2012 rate agreement by $30 million to $370 million . See Revenues and Rates - FPL Rates Effective January 2013 through December 2016 below. In December 2016, FPL retired the Cedar Bay generation facility. 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. Revenues and Rates - FPL's retail and wholesale utility rate schedules are approved by the FPSC and the FERC, respectively. FPL records unbilled base revenues for the estimated amount of energy delivered to customers but not yet billed. FPL's unbilled base revenues are included in customer receivables on NEE's and FPL's consolidated balance sheets and amounted to approximately $261 million and $246 million at December 31, 2016 and 2015 , respectively. FPL's operating revenues also include amounts resulting from cost recovery clauses (see Rate Regulation above), franchise fees, gross receipts taxes and surcharges related to storm-recovery bonds (see Note 8 - FPL). Franchise fees and gross receipts taxes are imposed on FPL; however, the FPSC allows FPL to include in the amounts charged to customers the amount of the gross receipts tax for all customers and the franchise fee for those customers located in the jurisdiction that imposes the amount. Accordingly, franchise fees and gross receipts taxes are reported gross in operating revenues and taxes other than income taxes and other in NEE's and FPL's consolidated statements of income and were approximately $700 million , $722 million and $716 million in 2016, 2015 and 2014 , respectively. The revenues from the surcharges related to storm-recovery bonds included in operating revenues in NEE's and FPL's consolidated statements of income were approximately $119 million , $115 million and $109 million in 2016, 2015 and 2014 , 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. FPL Rates Effective January 2017 through December 2020 - In December 2016, the FPSC issued a final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2016 rate agreement). Key elements of the 2016 rate agreement, which is effective from January 2017 through at least December 2020, include, among other things, the following: • New retail base rates and charges were established resulting in the following increases in annualized retail base revenues: ◦ $400 million beginning January 1, 2017; ◦ $211 million beginning January 1, 2018; and ◦ $200 million when a new approximately 1,750 MW natural gas-fired combined-cycle unit in Okeechobee County, Florida achieves commercial operation, which is expected to occur in mid-2019. • In addition, FPL is eligible to receive, subject to conditions specified in the 2016 rate agreement, base rate increases associated with the addition of up to 300 MW annually of new solar generation in each of 2017 through 2020 and may carry forward any unused MW to subsequent years during the term of the 2016 rate agreement. FPL will be required to demonstrate that any proposed solar facilities are cost effective and scheduled to be in service before December 31, 2021. FPL has agreed to an installed cost cap of $1,750 per kilowatt (kW). • FPL's allowed regulatory return on common equity (ROE) is 10.55% , with a range of 9.60% to 11.60% . If FPL's earned regulatory ROE falls below 9.60% , FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.60% , any party other than FPL may seek a review of FPL's retail base rates. • Subject to certain conditions, FPL may amortize, over the term of the 2016 rate agreement, up to $1.0 billion of depreciation reserve surplus plus the reserve amount remaining under FPL's 2012 rate agreement discussed below (approximately $250 million ), provided that in any year of the 2016 rate agreement, FPL must amortize at least enough reserve to maintain a 9.60% earned regulatory ROE but may not amortize any reserve that would result in an earned regulatory ROE in excess of 11.60% . • Future storm restoration costs would be recoverable on an interim basis beginning 60 days from the filing of a cost recovery petition, but capped at an amount that could produce a surcharge of no more than $4 for every 1,000 kilowatt-hour (kWh) of usage on residential bills during the first 12 months of cost recovery. Any additional costs would be eligible for recovery in subsequent years. If storm restoration costs exceed $800 million in any given calendar year, FPL may request an increase to the $4 surcharge to recover amounts above $400 million . In January 2017, the Sierra Club filed a notice of appeal challenging the FPSC’s final order approving the 2016 rate agreement, which notice of appeal is pending before the Florida Supreme Court. FPL Rates Effective January 2013 through December 2016 - Effective January 2013, pursuant to an FPSC final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2012 rate agreement), new retail base rates and charges for FPL were established resulting in an increase in retail base revenues of $350 million on an annualized basis. The 2012 rate agreement, provided for, among other things, the following: • a regulatory ROE of 10.50% with a range of plus or minus 100 basis points; • an increase in annualized base revenue requirements as each of three FPL modernized power plants became operational in April 2013, April 2014 and April 2016; • the continuation of cost recovery through the capacity clause (reported as retail base revenues) for a generating unit which was placed in service in May 2011 (beginning January 2017, under the 2016 rate agreement, cost recovery will be through base rates); • subject to certain conditions, the right to reduce depreciation expense up to $400 million (reserve), provided that in any year of the 2012 rate agreement, FPL was required to amortize enough reserve to maintain an earned regulatory ROE within the range of 9.50% to 11.50% (see Rate Regulation above regarding a subsequent reduction in the reserve amount); • an interim cost recovery mechanism for storm restoration costs (see Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve below); and • an incentive mechanism whereby customers receive 100% of certain gains, including but not limited to, gains from the purchase and sale of electricity and natural gas (including transportation and storage), up to a specified threshold; gains exceeding that specified threshold were shared by FPL and its customers. NEER's revenue is recorded on the basis of commodities delivered, contracts settled or services rendered and includes estimated amounts yet to be billed to customers. Certain 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. In May 2014, the Financial Accounting Standards Board (FASB) issued an accounting standards update which provides guidance on the recognition of revenue from contracts with customers and requires additional disclosures about the nature, amount, timing and uncertainty of revenue and cash flows from an entity's contracts with customers. The standards update will be effective for NEE and FPL beginning January 1, 2018 with early adoption on January 1, 2017 permitted. The standards update may be applied retrospectively to each prior period presented or retrospectively with the cumulative effect recognized as an adjustment to retained earnings as of the date of initial application (modified retrospective method). NEE and FPL are currently reviewing individual contracts within various identified revenue streams in order to determine the impact, if any, this standards update will have on their consolidated financial statements. A number of industry-specific implementation issues are still unresolved and the final resolution of certain of these issues could impact NEE's and/or FPL's current accounting policies and/or revenue recognition patterns. NEE and FPL currently anticipate adopting the standards update on January 1, 2018 using the modified retrospective method. Electric Plant, Depreciation and Amortization - The cost of additions to units of property of FPL and NEER is added to electric plant in service. 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. At December 31, 2016 , the electric generation, transmission, distribution and general facilities of FPL represented approximately 50% , 11% , 33% and 6% , respectively, of FPL's gross investment in electric utility plant in service and other property. Substantially all of FPL's properties are subject to the lien of FPL's mortgage, which secures most debt securities issued by FPL. A number of NEER's generation and pipeline facilities are encumbered by liens securing various financings. The net book value of NEER's assets serving as collateral was approximately $15.5 billion at December 31, 2016 . The American Recovery and Reinvestment Act of 2009, as amended (Recovery Act), provided for an option to elect a cash grant (convertible investment tax credits (ITCs)) for certain renewable energy property (renewable property). Convertible ITCs are recorded as a reduction in property, plant and equipment on NEE's and FPL's consolidated balance sheets and are amortized as a reduction to depreciation and amortization expense over the estimated life of the related property. At December 31, 2016 and 2015 , convertible ITCs, net of amortization, were approximately $2.1 billion ( $147 million at FPL) and $1.8 billion ( $153 million at FPL). At December 31, 2016 and 2015 , approximately $289 million and $207 million , respectively, of such convertible ITCs are included primarily in other receivables on NEE's consolidated balance sheets. Depreciation of FPL's electric property is primarily provided on a straight-line average remaining life basis. FPL includes in depreciation expense a provision for fossil and solar plant dismantlement, interim asset removal costs, accretion related to asset retirement obligations (see Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below), storm recovery amortization and amortization of pre-construction costs associated with planned nuclear units recovered through a cost recovery clause. For substantially all of FPL's property, depreciation studies are typically performed and filed with the FPSC every four years. In accordance with the 2012 rate agreement, FPL was not required to file depreciation studies during the effective period of the agreement; therefore, previously approved depreciation rates which became effective January 1, 2010 remained in effect through December 2016. As discussed in Revenues and Rates above, the use of reserve amortization was permitted under the 2012 rate agreement. In accordance with the 2012 rate agreement, FPL recorded reserve amortization (reversal) of approximately $13 million , $(15) million and $(33) million in 2016, 2015 and 2014 , respectively. The reserve is amortized as a reduction of (or reversed as an increase to) accrued asset removal costs which is reflected in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. The weighted annual composite depreciation and amortization rate for FPL's electric utility plant in service, including capitalized software, but excluding the effects of decommissioning, dismantlement and the depreciation adjustments discussed above, was approximately 3.4% , 3.3% and 3.3% for 2016, 2015 and 2014 , respectively. As part of the 2016 rate agreement, the FPSC approved new depreciation rates which became effective January 1, 2017. These new rates are expected to increase depreciation expense. The 2016 rate agreement also permits reserve amortization during the term of the agreement. See Revenues and Rates above. FPL files a twelve-month forecast with the FPSC each year which contains a regulatory ROE intended to be earned based on the best information FPL has at that time assuming normal weather. This forecast establishes a fixed targeted regulatory ROE. In order to earn the targeted regulatory ROE in each reporting period under the 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. NEER's electric plant in service less salvage value, if any, are depreciated primarily using the straight-line method over their estimated useful lives. At December 31, 2016 and 2015 , wind, nuclear, natural gas and solar plants represented approximately 62% and 62% , 10% and 11% , less than 1% and 3% , and 14% and 9% , respectively, of NEER's depreciable electric plant in service and other property. The estimated useful lives of NEER's plants range primarily from 25 to 30 years for wind, natural gas and solar plants and from 25 to 47 years for nuclear plants. NEER reviews the estimated useful lives of its fixed assets on an ongoing basis. NEER's oil and gas production assets, representing approximately 8% and 7% , respectively, of NEER's depreciable electric plant in service and other property at December 31, 2016 and 2015 , 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 13 - 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 non-cash item which represents the allowed cost of capital, including an ROE, used to finance construction projects. The portion of AFUDC attributable to borrowed funds is recorded as a reduction of interest expense and the remainder is recorded as other income. For FPL, FPSC rules limit the recording of AFUDC to projects that have an estimated cost in excess of 0.5% of a utility's plant in service balance and require more than one year to complete. FPSC rules allow construction projects below the 0.5% threshold as a component of rate base. During each of 2016, 2015 and 2014 , FPL capitalized AFUDC at a rate of 6.34% , which amounted to approximately $97 million , $88 million and $50 million , respectively. See Note 13 - Commitments. 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 a power plant or sale of development rights. At December 31, 2016 and 2015 , NEER's capitalized development costs totaled approximately $193 million and $133 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 no longer probable that these costs will 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 capitalized on construction projects amounted to approximately $107 million , $100 million and $104 million during 2016, 2015 and 2014 , respectively. Interest expense allocated from NextEra Energy Capital Holdings, Inc. (NEECH) to NEER is based on a deemed capital structure of 70% debt. Upon commencement of plant 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. The asset retirement cost is subsequently allocated to expense, for NEE's non-rate regulated operations, and regulatory liability, for FPL, 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 the consolidated statements of income for NEE's non-rate regulated operations, and ARO and regulatory liability, in the case of FPL. 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, in the case of NEE's non-rate regulated operations, and ARO and regulatory liability, in the case of FPL. See Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below and Note 12. Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs - For ratemaking purposes, FPL accrues for the cost of end of life retirement and disposal of its nuclear, fossil and solar plants over the expected service life of each unit based on nuclear decommissioning and fossil and solar dismantlement studies periodically filed with the FPSC. In addition, FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC. As approved by the FPSC, FPL previously suspended its annual decommissioning accrual. For financial reporting purposes, FPL recognizes decommissioning and dismantlement liabilities in accordance with accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred. Any differences between expense recognized for financial reporting purposes and the amount recovered through rates are reported as a regulatory liability in accordance with regulatory accounting. See Revenues and Rates, Electric Plant, Depreciation and Amortization, Asset Retirement Obligations above and Note 12. Nuclear decommissioning studies are performed at least every five years and are submitted to the FPSC for approval. FPL filed updated nuclear decommissioning studies with the FPSC in December 2015. These studies reflect FPL's current plans, under the operating licenses, for prompt dismantlement of Turkey Point Units Nos. 3 and 4 following the end of plant operation with decommissioning activities commencing in 2032 and 2033, respectively, and provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the prompt 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. The studies indicate 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, to be approximately $7.5 billion , or $3.0 billion expressed in 2016 dollars. Restricted funds for the payment of future expenditures to decommission FPL's nuclear units are included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's and FPL's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily classified as available for sale and 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 offset in the related regulatory liability accounts. FPL does not currently make contributions to the decommissioning funds, other than the reinvestment of fund earnings. During 2016 , 2015 and 2014 fund earnings on decommissioning funds were approximately $102 million , $96 million and $91 million , respectively. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. Fossil and solar plant dismantlement studies are typically performed at least every four years and are submitted to the FPSC for approval. In accordance with the 2012 rate agreement, FPL was not required to file fossil and solar dismantlement studies during the effective period of the agreement; therefore, previously approved studies which became effective January 1, 2010 remained in effect through December 2016 and resulted in an annual expense of $18 million which is recorded in depreciation and amortization expense in NEE's and FPL's consolidated statements of income. As part of the 2016 rate agreement, the FPSC approved a new annual expense of $26 million based on FPL's 2016 fossil and solar dismantlement studies which became effective January 1, 2017. At December 31, 2016 , FPL's portion of the ultimate cost to dismantle its fossil and solar units is approximately $1.3 billion , or $480 million expressed in 2016 dollars. NEER records 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, when required in accordance with accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred. The liabilities are being accreted using the interest method through the date decommissioning or dismantlement activities are expected to be complete. See Note 12. At December 31, 2016 and 2015 , NEER's ARO, which is primarily related to nuclear decommissioning and wind and solar dismantlement, was approximately $817 million and $647 million , respectively, and was primarily determined using various internal and external data and applying a probability percentage to a variety of scenarios regarding the life of the plant and timing of decommissioning or dismantlement. NEE

Employee Retirement Benefits

Employee Retirement Benefits	12 Months Ended
	Dec. 31, 2016
Compensation and Retirement Disclosure [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 $325 million ( $222 million for FPL) and $321 million ( $230 million for FPL) at December 31, 2016 and 2015 , 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: 2016 2015 (millions) Change in pension plan assets: Fair value of plan assets at January 1 $ 3,563 $ 3,698 Actual return on plan assets 217 (8 ) Benefit payments (129 ) (127 ) Fair value of plan assets at December 31 $ 3,651 $ 3,563 Change in pension benefit obligation: Obligation at January 1 $ 2,408 $ 2,454 Service cost 62 70 Interest cost 105 97 Plan amendments (19 ) — Actuarial losses (gains) - net 47 (86 ) Benefit payments (129 ) (127 ) Obligation at December 31 (a) $ 2,474 $ 2,408 Funded status: Prepaid pension benefit costs at NEE at December 31 $ 1,177 $ 1,155 Prepaid pension benefit costs at FPL at December 31 $ 1,301 $ 1,243 _________________________ (a) NEE's accumulated pension benefit obligation, which includes no assumption about future salary levels, at December 31, 2016 and 2015 was approximately $ 2,439 million and $ 2,366 million , respectively. 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: 2016 2015 (millions) Unrecognized prior service benefit (cost) (net of $2 tax expense and $1 tax benefit, respectively) $ 3 $ (2 ) Unrecognized losses (net of $55 and $38 tax benefit, respectively) (87 ) (60 ) Total $ (84 ) $ (62 ) NEE's unrecognized amounts included in regulatory assets yet to be recognized as components of net prepaid pension benefit costs are as follows: 2016 2015 (millions) Unrecognized prior service cost (benefit) $ (4 ) $ 9 Unrecognized losses 280 232 Total $ 276 $ 241 The following table provides the assumptions used to determine the benefit obligation for the pension plan. These rates are used in determining net periodic income in the following year. 2016 2015 Discount rate (a) 4.09 % 4.35 % Salary increase 4.10 % 4.10 % _________________________ (a) Beginning in 2017, NEE changed its method of estimating the interest cost component of net periodic benefit costs and will use a full yield curve approach by applying a specific spot rate along the yield curve rather than a single weighted-average discount rate. Such change is not expected to have a material impact on the pension and postretirement plans' net periodic benefit costs. NEE's investment policy for the pension plan recognizes the benefit of protecting the plan's funded status, thereby avoiding the necessity of future employer contributions. Its broad objectives are to achieve a high rate of total return with a prudent level of risk taking while maintaining sufficient liquidity and diversification to avoid large losses and preserve capital over the long term. The NEE pension plan fund's current target asset allocation, which is expected to be reached over time, is 45% equity investments, 32% fixed income investments, 13% alternative investments and 10% convertible securities. The pension fund's investment strategy emphasizes traditional investments, broadly diversified across the global equity and fixed income markets, using a combination of different investment styles and vehicles. The pension fund's equity and fixed income holdings consist of both directly held securities as well as commingled investment arrangements such as common and collective trusts, pooled separate accounts, registered investment companies and limited partnerships. The pension fund's convertible security assets are principally direct holdings of convertible securities and include a convertible security oriented limited partnership. The pension fund's alternative investments consist primarily of private equity and real estate oriented investments in limited partnerships as well as absolute return oriented limited partnerships that use a broad range of investment strategies on a global basis. The fair value measurements of NEE's pension plan assets by fair value hierarchy level are as follows: December 31, 2016 (a) Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total (millions) Equity securities (b) $ 879 $ 16 $ 3 $ 898 Equity commingled vehicles (c) — 845 — 845 U.S. Government and municipal bonds 143 12 — 155 Corporate debt securities (d) 3 246 1 250 Asset-backed securities — 124 — 124 Debt security commingled vehicles — 22 — 22 Convertible securities (e) 21 277 — 298 Total investments in the fair value hierarchy $ 1,046 $ 1,542 $ 4 2,592 Total investments measured at net asset value (f) 1,059 Total fair value of plan assets $ 3,651 ______________________ (a) See Note 4 for discussion of fair value measurement techniques and inputs. (b) Includes foreign investments of $ 370 million . (c) Includes foreign investments of $ 261 million . (d) Includes foreign investments of $ 67 million . (e) Includes foreign investments of $ 31 million . (f) Includes foreign investments of $ 282 million . December 31, 2015 (a) Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total (millions) Equity securities (b) $ 910 $ 21 $ 1 $ 932 Equity commingled vehicles (c) — 792 — 792 U.S. Government and municipal bonds 110 13 — 123 Corporate debt securities (d) 2 277 1 280 Asset-backed securities — 167 — 167 Debt security commingled vehicles — 21 — 21 Convertible securities (e) 16 258 — 274 Total investments in the fair value hierarchy $ 1,038 $ 1,549 $ 2 2,589 Total investments measured at net asset value (f) 974 Total fair value of plan assets $ 3,563 ______________________ (a) See Note 4 for discussion of fair value measurement techniques and inputs. (b) Includes foreign investments of $ 384 million . (c) Includes foreign investments of $ 249 million . (d) Includes foreign investments of $ 68 million . (e) Includes foreign investments of $ 23 million . (f) Includes foreign investments of $ 283 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): 2017 $ 155 2018 $ 156 2019 $ 160 2020 $ 163 2021 $ 170 2022 - 2026 $ 879 Net Periodic (Income) Cost - The components of net periodic (income) cost for the plans are as follows: Pension Benefits Postretirement Benefits 2016 2015 2014 2016 2015 2014 (millions) Service cost $ 62 $ 70 $ 61 $ 2 $ 3 $ 3 Interest cost 105 97 101 13 13 16 Expected return on plan assets (260 ) (253 ) (241 ) (1 ) (1 ) (1 ) Amortization of prior service cost (benefit) 1 1 5 (2 ) (3 ) (3 ) Amortization of losses — — — — 2 — Net periodic (income) cost at NEE $ (92 ) $ (85 ) $ (74 ) $ 12 $ 14 $ 15 Net periodic (income) cost at FPL $ (58 ) $ (55 ) $ (47 ) $ 9 $ 11 $ 11 Other Comprehensive Income - The components of net periodic income (cost) recognized in OCI for the pension plan are as follows: 2016 2015 2014 (millions) Prior service benefit (net of $3 and $3 tax expense, respectively) $ 4 $ — $ 4 Net losses (net of $16, $27 and $29 tax benefit, respectively) (26 ) (44 ) (45 ) Amortization of prior service benefit — — 1 Total $ (22 ) $ (44 ) $ (40 ) Regulatory Assets (Liabilities) - The components of net periodic (income) cost recognized during the year in regulatory assets (liabilities) for the pension plan are as follows: 2016 2015 (millions) Prior service benefit $ (12 ) $ — Unrecognized losses 48 104 Amortization of prior service benefit (1 ) (1 ) Total $ 35 $ 103 The assumptions used to determine net periodic income for the pension plan are as follows: 2016 2015 2014 Discount rate 4.35 % 3.95 % 4.80 % Salary increase 4.10 % 4.10 % 4.00 % Expected long-term rate of return (a)(b) 7.35 % 7.35 % 7.75 % ______________________ (a) In developing the expected long-term rate of return on assets assumption for its pension plan, NEE evaluated input, including other qualitative and quantitative factors, from its actuaries and consultants, as well as information available in the marketplace. NEE considered different models, capital market return assumptions and historical returns for a portfolio with an equity/bond asset mix similar to its pension fund. NEE also considered its pension fund's historical compounded returns. (b) In 2016 and 2015, an expected long-term rate of return of 7.75% is presented net of investment management fees. Employee Contribution Plan - NEE offers an employee retirement savings plan which allows eligible participants to contribute a percentage of qualified compensation through payroll deductions. NEE makes matching contributions to participants' accounts. Defined contribution expense pursuant to this plan was approximately $ 52 million , $ 63 million and $ 59 million for NEE ($ 32 million , $ 40 million and $ 37 million for FPL) for the years ended December 31, 2016 , 2015 and 2014 , respectively.

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2016
Derivative Instruments [Abstract]
Derivative Instruments	Derivative Instruments NEE and FPL use derivative instruments (primarily swaps, options, futures and forwards) to manage the commodity price risk 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. 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 gas marketing and trading activities to take advantage of expected future favorable price movements and changes in the expected volatility of prices in the energy markets. These risk management activities involve the use of derivative instruments executed within prescribed limits to manage the risk associated with fluctuating commodity prices. Transactions in derivative instruments are executed on recognized exchanges or via the over-the-counter (OTC) markets, depending on the most favorable credit terms and market execution factors. For NEER's power generation and gas infrastructure assets, derivative instruments are used to hedge all or a portion of the expected output of these assets. These hedges are designed to reduce the effect of adverse changes in the wholesale forward commodity markets associated with NEER's power generation and gas infrastructure assets. With regard to full energy and capacity requirements services, NEER is required to vary the quantity of energy and related services based on the load demands of the customers served. For this type of transaction, derivative instruments are used to hedge the anticipated electricity quantities required to serve these customers and reduce the effect of unfavorable changes in the forward energy markets. Additionally, NEER takes positions in energy markets based on differences between actual forward market levels and management's view of fundamental market conditions, including supply/demand imbalances, changes in traditional flows of energy, changes in short- and long-term weather patterns and anticipated regulatory and legislative outcomes. NEER uses derivative instruments to realize value from these market dislocations, subject to strict risk management limits around market, operational and credit exposure. Derivative instruments, when required to be marked to market, are recorded on NEE's and FPL's consolidated balance sheets as either an asset or liability measured at fair value. At FPL, substantially all changes in the derivatives' fair value are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the fuel and purchased power cost recovery clause (fuel clause). For NEE's non-rate regulated operations, predominantly NEER, essentially all changes in the derivatives' fair value for power purchases and sales, fuel sales and trading activities are recognized on a net basis in operating revenues; fuel purchases used in the production of electricity are recognized in fuel, purchased power and interchange expense; and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's consolidated statements of income. Settlement gains and losses are included within the line items in the consolidated statements of income to which they relate. Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the consolidated statements of income. For commodity derivatives, NEE believes that, where offsetting positions exist at the same location for the same time, the transactions are considered to have been netted and therefore physical delivery has been deemed not to have occurred for financial reporting purposes. Settlements related to derivative instruments are primarily recognized in net cash provided by operating activities in NEE's and FPL's consolidated statements of cash flows. In January 2016, NEE discontinued hedge accounting for its cash flow and fair value hedges related to interest rate and foreign currency derivative instruments and, therefore, all changes in the derivatives' fair value, as well as the transaction gain or loss on foreign denominated debt, are recognized in interest expense in NEE's consolidated statements of income. In addition, for the year ended December 31, 2016 , NEE reclassified approximately $18 million ( $11 million after tax), respectively, from AOCI to interest expense primarily because it became probable that a related future transaction being hedged would not occur. At December 31, 2016 , NEE's AOCI included amounts related to the 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 $80 million of net losses included in AOCI at December 31, 2016 is 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 of Derivative Instruments - The tables below present NEE's and FPL's gross derivative positions at December 31, 2016 and December 31, 2015 , 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 (see Note 4 - Recurring Fair Value Measurements for netting information), as well as the location of the net derivative position on the consolidated balance sheets. December 31, 2016 Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis Fair Values of Derivatives Not Assets Liabilities Assets Liabilities (millions) NEE: Commodity contracts $ 4,590 $ 2,968 $ 1,938 $ 483 Interest rate contracts 288 284 296 292 Foreign currency contracts 1 106 1 106 Total fair values $ 4,879 $ 3,358 $ 2,235 $ 881 FPL: Commodity contracts $ 212 $ 4 $ 209 $ 1 Net fair value by NEE balance sheet line item: Current derivative assets (a) $ 885 Noncurrent derivative assets (b) 1,350 Current derivative liabilities $ 404 Noncurrent derivative liabilities 477 Total derivatives $ 2,235 $ 881 Net fair value by FPL balance sheet line item: Current derivative assets $ 209 Current derivative liabilities $ 1 Total derivatives $ 209 $ 1 ______________________ (a) Reflects the netting of approximately $96 million in margin cash collateral received from counterparties. (b) Reflects the netting of approximately $71 million in margin cash collateral received from counterparties. December 31, 2015 Fair Values of Derivatives Designated as Hedging Instruments for Accounting Purposes - Gross Basis Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis Total Derivatives Combined - Net Basis Assets Liabilities Assets Liabilities Assets Liabilities (millions) NEE: Commodity contracts $ — $ — $ 5,906 $ 4,580 $ 1,937 $ 982 Interest rate contracts 33 155 2 160 34 319 Foreign currency contracts — 132 — — — 127 Total fair values $ 33 $ 287 $ 5,908 $ 4,740 $ 1,971 $ 1,428 FPL: Commodity contracts $ — $ — $ 7 $ 225 $ 4 $ 222 Net fair value by NEE balance sheet line item: Current derivative assets (a) $ 712 Assets held for sale 57 Noncurrent derivative assets (b) 1,202 Current derivative liabilities (c) $ 882 Liabilities associated with assets held for sale 16 Noncurrent derivative liabilities (d) 530 Total derivatives $ 1,971 $ 1,428 Net fair value by FPL balance sheet line item: Current derivative assets $ 3 Noncurrent other assets 1 Current derivative liabilities $ 222 Total derivatives $ 4 $ 222 ______________________ (a) Reflects the netting of approximately $279 million in margin cash collateral received from counterparties. (b) Reflects the netting of approximately $151 million in margin cash collateral received from counterparties. (c) Reflects the netting of approximately $46 million in margin cash collateral paid to counterparties. (d) Reflects the netting of approximately $13 million in margin cash collateral paid to counterparties. At December 31, 2016 and 2015 , NEE had approximately $5 million and $27 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, 2016 and 2015 , NEE had approximately $129 million and $116 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. Income Statement Impact of Derivative Instruments - Losses related to NEE's cash flow hedges, which were previously designated as hedging instruments, are recorded in NEE's consolidated financial statements (none at FPL) as follows: Year Ended Year Ended Interest Rate Contracts Foreign Currency Contracts Total Interest Rate Contracts Foreign Currency Contracts Total Losses recognized in OCI $ (113 ) $ (12 ) $ (125 ) $ (132 ) $ (89 ) $ (221 ) Losses reclassified from AOCI to net income $ (73 ) (a) $ (15 ) (b) $ (88 ) $ (77 ) (a) $ (78 ) (b) $ (155 ) ______________________ (a) Included in interest expense. (b) For 2015 and 2014, losses of approximately $11 million and $8 million , respectively, are included in interest expense and the balances are included in other - net. Gains (losses) related to NEE's derivatives not designated as hedging instruments are recorded in NEE's consolidated statements of income as follows: Years Ended December 31, 2016 2015 2014 (millions) Commodity contracts: (a) Operating revenues $ 459 $ 932 $ 420 Fuel, purchased power and interchange (1 ) 8 1 Foreign currency contracts - interest expense 14 — — Foreign currency contracts - other - net (1 ) — (1 ) Interest rate contracts - interest expense 181 8 (64 ) Losses reclassified from AOCI to interest expense: Interest rate contracts (90 ) — — Foreign currency contracts (11 ) — — Total $ 551 $ 948 $ 356 ______________________ (a) For the years ended December 31, 2016 , 2015 and 2014 , FPL recorded gains (losses) of approximately $203 million , $(326) million and $(289) million , respectively, related to commodity contracts as regulatory liabilities (assets) on its consolidated balance sheets. 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 their 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, 2016 December 31, 2015 Commodity Type NEE FPL NEE FPL (millions) Power (84 ) MWh (a) — (112 ) MWh (a) — Natural gas 1,002 MMBtu (b) 618 MMBtu (b) 1,321 MMBtu (b) 833 MMBtu (b) Oil (7 ) barrels — (9 ) barrels — ______________________ (a) Megawatt-hours (b) One million British thermal units At December 31, 2016 and 2015 , NEE had interest rate contracts with notional amounts totaling approximately $15.1 billion and $8.3 billion , respectively, and foreign currency contracts with notional amounts totaling approximately $705 million and $715 million , 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, 2016 and 2015 , the aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately $1.3 billion ( $5 million for FPL) and $2.2 billion ( $224 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 two 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 $110 million ( none at FPL) and $165 million ( $20 million at FPL) as of December 31, 2016 and 2015 , 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 $990 million ( $10 million at FPL) and $1.4 billion ( $185 million at FPL) as of December 31, 2016 and 2015 , 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 $225 million ( $115 million at FPL) and $270 million ( $120 million at FPL) as of December 31, 2016 and 2015 , 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, 2016 , applicable NEE subsidiaries have posted approximately $1 million ( none at FPL) in cash and $30 million ( none at FPL) in the form of letters of credit which could be applied toward the collateral requirements described above. At December 31, 2015 , applicable NEE subsidiaries have posted approximately $123 million ( $3 million at FPL) in the form of letters of credit which could be applied toward the collateral requirements described above. FPL and NEECH have 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 where 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.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements 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. Cash Equivalents and Restricted Cash - NEE primarily holds investments in money market funds. The fair value of these funds is estimated using a market approach based on current observable market prices. Special Use Funds and Other Investments - NEE and FPL hold primarily debt and equity securities directly, as well as indirectly through commingled funds. Substantially all directly held equity securities are valued at their quoted market prices. For directly held debt securities, multiple prices and price types are obtained from pricing vendors whenever possible, which enables cross-provider validations. A primary price source is identified based on asset type, class or issue of each security. Commingled funds, which are similar to mutual funds, are maintained by banks or investment companies and hold certain investments in accordance with a stated set of objectives. The fair value of commingled funds is primarily derived from the quoted prices in active markets of the underlying securities. Because the fund shares are offered to a limited group of investors, they are not considered to be traded in an active market. Derivative Instruments - 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. Recurring Fair Value Measurements - NEE's and FPL's financial assets and liabilities and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows: December 31, 2016 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: Cash equivalents and restricted cash: (b) NEE - equity securities $ 982 $ — $ — $ 982 FPL - equity securities $ 120 $ — $ — $ 120 Special use funds: (c) NEE: Equity securities $ 1,410 $ 1,503 (d) $ — $ 2,913 U.S. Government and municipal bonds $ 296 $ 170 $ — $ 466 Corporate debt securities $ 1 $ 763 $ — $ 764 Mortgage-backed securities $ — $ 498 $ — $ 498 Other debt securities $ — $ 81 $ — $ 81 FPL: Equity securities $ 373 $ 1,372 (d) $ — $ 1,745 U.S. Government and municipal bonds $ 221 $ 141 $ — $ 362 Corporate debt securities $ — $ 547 $ — $ 547 Mortgage-backed securities $ — $ 384 $ — $ 384 Other debt securities $ — $ 70 $ — $ 70 Other investments: NEE: Equity securities $ 26 $ 9 $ — $ 35 Debt securities $ 8 $ 153 $ — $ 161 Derivatives: NEE: Commodity contracts $ 1,563 $ 1,827 $ 1,200 $ (2,652 ) $ 1,938 (e) Interest rate contracts $ — $ 285 $ 3 $ 8 $ 296 (e) Foreign currency contracts $ — $ 1 $ — $ — $ 1 (e) FPL - commodity contracts $ — $ 208 $ 4 $ (3 ) $ 209 (e) Liabilities: Derivatives: NEE: Commodity contracts $ 1,476 $ 980 $ 512 $ (2,485 ) $ 483 (e) Interest rate contracts $ — $ 171 $ 113 $ 8 $ 292 (e) Foreign currency contracts $ — $ 106 $ — $ — $ 106 (e) FPL - commodity contracts $ — $ 1 $ 3 $ (3 ) $ 1 (e) ______________________ (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) Includes restricted cash of approximately $164 million ( $120 million for FPL) in other current assets on the consolidated balance sheets. (c) 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. (d) Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL. (e) See Note 3 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's consolidated balance sheets. December 31, 2015 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: Cash equivalents and restricted cash: (b) NEE - equity securities $ 312 $ — $ — $ 312 FPL - equity securities $ 36 $ — $ — $ 36 Special use funds: (c) NEE: Equity securities $ 1,320 $ 1,354 (d) $ — $ 2,674 U.S. Government and municipal bonds $ 446 $ 166 $ — $ 612 Corporate debt securities $ — $ 713 $ — $ 713 Mortgage-backed securities $ — $ 412 $ — $ 412 Other debt securities $ — $ 52 $ — $ 52 FPL: Equity securities $ 364 $ 1,234 (d) $ — $ 1,598 U.S. Government and municipal bonds $ 335 $ 145 $ — $ 480 Corporate debt securities $ — $ 531 $ — $ 531 Mortgage-backed securities $ — $ 327 $ — $ 327 Other debt securities $ — $ 40 $ — $ 40 Other investments: NEE: Equity securities $ 30 $ 10 $ — $ 40 Debt securities $ 39 $ 132 $ — $ 171 Derivatives: NEE: Commodity contracts $ 2,187 $ 2,540 $ 1,179 $ (3,969 ) $ 1,937 (e) Interest rate contracts $ — $ 35 $ — $ (1 ) $ 34 (e) FPL - commodity contracts $ — $ 1 $ 6 $ (3 ) $ 4 (e) Liabilities: Derivatives: NEE: Commodity contracts $ 2,153 $ 1,887 $ 540 $ (3,598 ) $ 982 (e) Interest rate contracts $ — $ 214 $ 101 $ 4 $ 319 (e) Foreign currency contracts $ — $ 132 $ — $ (5 ) $ 127 (e) FPL - commodity contracts $ — $ 219 $ 6 $ (3 ) $ 222 (e) ______________________ (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) Includes restricted cash of approximately $61 million ( $36 million for FPL) in other current assets on the consolidated balance sheets. (c) 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. (d) Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL. (e) See Note 3 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL'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, 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. All price, volatility, correlation and customer migration inputs used in valuation are subject to validation by the Trading Risk Management group. The Trading Risk Management group performs a risk management function responsible for assessing credit, market and operational risk impact, reviewing valuation methodology and modeling, confirming transactions, monitoring approval processes and developing and monitoring trading limits. The Trading Risk Management group is separate from the transacting group. For markets where independent third-party data is readily available, validation is conducted daily by directly reviewing this market data against inputs utilized by the transacting group, and indirectly by reviewing daily risk reports. For markets where independent third-party data is not readily available, additional analytical reviews are performed on at least a quarterly basis. These analytical reviews are designed to ensure that all price and volatility curves used for fair valuing transactions are adequately validated each quarter, and are reviewed and approved by the Trading Risk Management group. In addition, other valuation assumptions such as implied correlations and customer migration rates are reviewed and approved by the Trading Risk Management group on a periodic basis. Newly created models used in the valuation process are also subject to testing and approval by the Trading Risk Management group prior to use and established models are reviewed annually, or more often as needed, by the Trading Risk Management group. On a monthly basis, the Exposure Management Committee (EMC), which is comprised of certain members of senior management, meets with representatives from the Trading Risk Management group and the transacting group to discuss NEE's and FPL's energy risk profile and operations, to review risk reports and to discuss fair value issues as necessary. The EMC develops guidelines required for an appropriate risk management control infrastructure, which includes implementation and monitoring of compliance with Trading Risk Management policy. The EMC executes its risk management responsibilities through direct oversight and delegation of its responsibilities to the Trading Risk Management group, as well as to other corporate and business unit personnel. 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, 2016 are as follows: Transaction Type Fair Value at December 31, 2016 Valuation Technique(s) Significant Unobservable Inputs Range Assets Liabilities (millions) Forward contracts - power $ 621 $ 206 Discounted cash flow Forward price (per MWh) $— — $91 Forward contracts - gas 27 10 Discounted cash flow Forward price (per MMBtu) $2 — $11 Forward contracts - other commodity related 7 1 Discounted cash flow Forward price (various) $(17) — $57 Options - power 43 10 Option models Implied correlations 1% — 100% Implied volatilities 9% — 296% Options - primarily gas 223 230 Option models Implied correlations 1% — 100% Implied volatilities 1% — 260% Full requirements and unit contingent contracts 279 55 Discounted cash flow Forward price (per MWh) $(20) — $220 Customer migration rate (a) —% — 20% Total $ 1,200 $ 512 ______________________ (a) Applies only to full requirements contracts. The sensitivity of NEE's fair value measurements to increases (decreases) in the significant unobservable inputs is as follows: Significant Unobservable Input Position Impact on Fair Value Measurement Forward price Purchase power/gas Increase (decrease) Sell power/gas Decrease (increase) Implied correlations Purchase option Decrease (increase) Sell option Increase (decrease) Implied volatilities Purchase option Increase (decrease) Sell option Decrease (increase) Customer migration rate Sell power (a) Decrease (increase) ———————————— (a) Assumes the contract is in a gain position. In addition, the fair value measurement of interest rate contract net liabilities related to the solar projects in Spain of approximately $110 million at December 31, 2016 includes a significant credit valuation adjustment. The credit valuation adjustment, considered an unobservable input, reflects management's assessment of non-performance risk of the subsidiaries related to the solar projects in Spain that are party to the contracts. See Note 11 - Spain Solar Projects Debt Restructuring for further discussion. The reconciliation of changes in the fair value of derivatives that are based on significant unobservable inputs is as follows: Years Ended December 31, 2016 2015 2014 NEE FPL NEE FPL NEE FPL (millions) Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year $ 538 $ — $ 622 $ 5 $ 622 $ — Realized and unrealized gains (losses): Included in earnings (a) 333 — 451 — (77 ) — Included in other comprehensive income 8 — 11 — 18 — Included in regulatory assets and liabilities 1 1 3 3 7 7 Purchases 261 — 180 — 55 — Settlements (390 ) — (473 ) (8 ) 194 (2 ) Issuances (195 ) — (202 ) — (122 ) — Transfers in (b) 19 — (13 ) — 80 — Transfers out (b) 3 — (41 ) — (155 ) — Fair value of net derivatives based on significant unobservable inputs at December 31 $ 578 $ 1 $ 538 $ — $ 622 $ 5 The amount of gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to derivatives still held at the reporting date (c) $ 219 $ — $ 277 $ — $ 248 $ — ______________________ (a) For the year ended December 31, 2016 , $397 million of realized and unrealized gains are reflected in the consolidated statements of income in operating revenues and the balance is reflected in interest expense. For the year ended December 31, 2015 , $462 million of realized and unrealized gains are reflected in the consolidated statements of income in operating revenues and the balance is primarily reflected in interest expense. For the year December 31, 2014 , $79 million of realized and unrealized losses are reflected in the consolidated statements of income in interest expense and the balance is primarily reflected in operating revenues. (b) 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 and, in 2016, a favorable change to a credit valuation adjustment. NEE's and FPL's policy is to recognize all transfers at the beginning of the reporting period. (c) For the years ended December 31, 2016 , 2015 and 2014 , $283 million , $289 million , and $328 million of unrealized gains are reflected in the consolidated statements of income in operating revenues and the balance is reflected in interest expense. Contingent Consideration - NEE recorded a liability related to a contingent holdback as part of the 2015 acquisition of a portfolio of seven long-term contracted natural gas pipeline assets located in Texas (Texas pipelines). See Note 7 - Texas Pipeline Business. Nonrecurring Fair Value Measurements - In 2013, NEER initiated a plan and received internal authorization to pursue the sale of its ownership interests in oil-fired generation plants located in Maine (Maine fossil), which resulted in the recording of a loss during that period which was reflected within discontinued operations at NEE. In 2014, NEER decided not to pursue the sale of Maine fossil due to the divergence between the achievable sales price and management's view of the assets' value, which increased as a result of significant market changes. Accordingly, the Maine fossil assets were written-up to management's current estimate of fair value resulting in a gain of approximately $ 21 million ($ 12 million after tax) which is included as a separate line item in NEE's consolidated statements of income. The fair value measurement (Level 3) was estimated using an income approach based primarily on the updated capacity revenue forecasts. Fair Value of Financial Instruments Recorded at Other than Fair Value - The carrying amounts of cash equivalents, 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, 2016 December 31, 2015 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value (millions) NEE: Special use funds (a) $ 712 $ 712 $ 675 $ 675 Other investments - primarily notes receivable $ 526 $ 668 (b) $ 512 $ 722 (b) Long-term debt, including current maturities (c) $ 30,418 $ 31,623 (d) $ 28,897 $ 30,412 (d) FPL: Special use funds (a) $ 557 $ 557 $ 528 $ 528 Long-term debt, including current maturities $ 10,072 $ 11,211 (d) $ 10,020 $ 11,028 (d) ______________________ (a) Primarily represents investments accounted for under the equity method and loans not measured at fair value on a recurring basis. (b) Primarily classified as held to maturity. Fair values are primarily estimated using an income approach utilizing a discounted cash flow valuation technique based on certain observable yield curves and indices considering the credit profile of the borrower (Level 3). Notes receivable bear interest primarily at fixed rates and mature by 2029 . Notes receivable are considered impaired and placed in non-accrual status when it becomes probable that all amounts due cannot be collected in accordance with the contractual terms of the agreement. The assessment to place notes receivable in non-accrual status considers various credit indicators, such as credit ratings and market-related information. (c) Excludes debt totaling $373 million and $938 million , respectively, reflected in liabilities associated with assets held for sale on NEE's consolidated balance sheets for which the carrying amount approximates fair value. See Note 1 - Assets and Liabilities Associated with Assets Held for Sale. (d) As of December 31, 2016 and 2015 , for NEE, approximately $29,804 million and $18,031 million , respectively, is estimated using a market approach based on quoted market prices for the same or similar issues (Level 2); the balance is estimated using an income approach utilizing a discounted cash flow valuation technique, considering the current credit profile of the debtor (Level 3). For FPL, primarily estimated using quoted market prices for the same or similar issues (Level 2). Special Use Funds - The special use funds noted above and those carried at fair value (see Recurring Fair Value Measurements above) consist of NEE's and FPL's nuclear decommissioning fund assets of $5,434 million and $5,064 million at December 31, 2016 and 2015 , respectively, ( $3,665 million and $3,430 million , respectively, for FPL) and, in 2015, FPL's storm fund assets of $74 million . The investments held in the special use funds consist of equity and debt securities which are primarily classified as available for sale and carried at estimated fair value. The amortized cost of debt and equity securities is approximately $ 1,820 million and $ 1,543 million , respectively, at December 31, 2016 and $ 1,823 million and $ 1,505 million , respectively, at December 31, 2015 ($ 1,373 million and $ 764 million , respectively, at December 31, 2016 and $ 1,409 million and $ 732 million , respectively, at December 31, 2015 for FPL). For FPL's special use funds, consistent with regulatory treatment, changes in fair value, including any other than temporary impairment losses, result in a corresponding adjustment to the related regulatory liability accounts. For NEE's non-rate regulated operations, changes in fair value result in a corresponding adjustment to OCI, except for unrealized losses associated with marketable securities considered to be other than temporary, including any credit losses, which are recognized as other than temporary impairment losses on securities held in nuclear decommissioning funds in NEE's consolidated statements of income. Debt securities included in the nuclear decommissioning funds have a weighted-average maturity at December 31, 2016 of approximately nine years at both NEE and FPL. The cost of securities sold is determined using the specific identification method. Realized gains and losses and proceeds from the sale or maturity of available for sale securities are as follows: NEE FPL Years Ended December 31, Years Ended December 31, 2016 2015 2014 2016 2015 2014 (millions) Realized gains $ 116 $ 194 $ 211 $ 53 $ 70 $ 120 Realized losses $ 76 $ 87 $ 115 $ 44 $ 43 $ 94 Proceeds from sale or maturity of securities $ 3,400 $ 4,643 $ 4,092 $ 2,442 $ 3,724 $ 3,349 The unrealized gains on available for sale securities are as follows: NEE FPL December 31, December 31, 2016 2015 2016 2015 (millions) Equity securities $ 1,396 $ 1,166 $ 1,007 $ 863 Debt securities $ 22 $ 17 $ 17 $ 14 The 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, 2016 2015 2016 2015 (millions) Unrealized losses (a) $ 34 $ 51 $ 28 $ 45 Fair value $ 959 $ 1,129 $ 722 $ 861 ______________________ (a) Unrealized losses on available for sale debt securities in an unrealized loss position for greater than twelve months at December 31, 2016 and 2015 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. Financial Instruments Accounting Standards Update - In January 2016, the FASB issued an accounting standards update which modifies current guidance for financial instruments. The standards update requires that equity investments (except investments accounted for under the equity method and investments that are consolidated) be measured at fair value with changes in fair value recognized in net income and provides an option for those equity investments that do not have readily determinable fair values to be measured at cost minus impairment (plus or minus changes resulting from observable price changes). The standards update also makes certain changes to presentation and disclosure requirements of financial instruments. The standards update is effective for NEE and FPL beginning January 1, 2018 and will be applied retrospectively with the cumulative effect recognized as of the date of initial application. NEE and FPL are currently evaluating the effect the adoption of this standards update will have, if any, on their consolidated financial statements.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The components of income taxes are as follows: NEE FPL Years Ended December 31, Years Ended December 31, 2016 2015 2014 2016 2015 2014 (millions) Federal: Current $ 72 $ 10 $ — $ 72 $ 423 $ 240 Deferred 1,075 1,194 1,077 830 399 542 Total federal 1,147 1,204 1,077 902 822 782 State: Current 76 31 (29 ) 57 58 68 Deferred 160 (7 ) 128 92 77 60 Total state 236 24 99 149 135 128 Total income taxes $ 1,383 $ 1,228 $ 1,176 $ 1,051 $ 957 $ 910 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, 2016 2015 2014 2016 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % Increases (reductions) resulting from: State income taxes - net of federal income tax benefit 3.5 0.4 1.8 3.5 3.4 3.4 PTCs and ITCs - NEER (3.9 ) (4.1 ) (5.1 ) — — — Convertible ITCs - NEER (1.7 ) (0.8 ) (1.4 ) — — — Adjustments associated with Canadian assets (0.7 ) — 1.3 — — — Other - net (0.7 ) 0.3 0.7 (0.7 ) (1.7 ) (0.9 ) Effective income tax rate 31.5 % 30.8 % 32.3 % 37.8 % 36.7 % 37.5 % 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, 2016 2015 2016 2015 (millions) Deferred tax liabilities: Property-related $ 13,094 $ 12,204 $ 8,882 $ 8,040 Pension 454 455 502 480 Nuclear decommissioning trusts 253 219 — — Net unrealized gains on derivatives 581 528 — — Investments in partnerships and joint ventures 603 403 — — Other 1,272 1,196 796 695 Total deferred tax liabilities 16,257 15,005 10,180 9,215 Deferred tax assets and valuation allowance: Decommissioning reserves 454 438 401 386 Postretirement benefits 145 141 93 95 Net operating loss carryforwards 427 604 3 4 Tax credit carryforwards 3,059 2,916 — — ARO and accrued asset removal costs 777 759 699 697 Other 1,024 836 443 303 Valuation allowance (a) (269 ) (223 ) — — Net deferred tax assets 5,617 5,471 1,639 1,485 Net deferred income taxes $ 10,640 $ 9,534 $ 8,541 $ 7,730 ______________________ (a) Amount relates to a valuation allowance related to the solar projects in Spain, 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, 2016 2015 2016 2015 (millions) Noncurrent other assets $ 461 $ 293 $ — $ — Deferred income taxes - noncurrent liabilities (11,101 ) (9,827 ) (8,541 ) (7,730 ) Net deferred income taxes $ (10,640 ) $ (9,534 ) $ (8,541 ) $ (7,730 ) The components of NEE's deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2016 are as follows: Amount Expiration Dates (millions) Net operating loss carryforwards: Federal $ 165 2026-2036 State 174 2017-2036 Foreign 88 (a) 2017-2036 Net operating loss carryforwards $ 427 Tax credit carryforwards: Federal $ 2,697 2022-2036 State 362 (b) 2017-2044 Tax credit carryforwards $ 3,059 ______________________ (a) Includes $ 60 million of net operating loss carryforwards with an indefinite expiration period. (b) Includes $ 188 million of ITC carryforwards with an indefinite expiration period.

Jointly-Owned Electric Plants

Jointly-Owned Electric Plants	12 Months Ended
	Dec. 31, 2016
Jointly-Owned Electric Plants [Abstract]
Jointly-Owned Electric Plants	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, 2016 Ownership Interest Gross Investment (a) Accumulated Depreciation (a) Construction Work in Progress (millions) FPL: St. Lucie Unit No. 2 85 % $ 2,172 $ 815 $ 33 St. Johns River Power Park units and coal terminal 20 % $ 393 $ 208 $ — Scherer Unit No. 4 76 % $ 1,138 $ 395 $ 3 NEER: Duane Arnold 70 % $ 466 $ 146 $ 16 Seabrook 88.23 % $ 1,138 $ 271 $ 77 Wyman Station Unit No. 4 84.35 % $ 25 $ 3 $ — Corporate and Other: Transmission substation assets located in Seabrook, New Hampshire 88.23 % $ 76 $ 17 $ 3 ______________________ (a) Excludes nuclear fuel.

Business Acquisitions Business

Business Acquisitions Business Acquisitions	12 Months Ended
	Dec. 31, 2016
Business Combinations [Abstract]
Business Acquisitions	Business Acquisitions Texas Pipeline Business - On October 1, 2015, a subsidiary of NEP acquired 100% of the membership interests in NET Holdings Management, LLC (Texas pipeline business), a developer, owner and operator of the Texas pipelines. One of the acquired pipelines is subject to a 10% noncontrolling interest. The aggregate purchase price of approximately $2 billion included approximately $934 million in cash consideration and the assumption of approximately $706 million in existing debt of the Texas pipeline business and its subsidiaries at closing and excluded post-closing working capital adjustments of approximately $2 million . The purchase price is subject to (i) a $200 million holdback payable, in whole or in part, upon satisfaction of financial performance and capital expenditure thresholds relating to planned expansion projects (contingent holdback) and (ii) a $200 million holdback retained to satisfy any indemnification obligations of the sellers through April 2017. NEP incurred approximately $13 million in acquisition-related costs during the year ended December 31, 2015, which are reflected in O&M expenses in NEE's consolidated statements of income. Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed on October 1, 2015 based on their estimated fair value. All fair value measurements of assets acquired and liabilities assumed, including the noncontrolling interest, were based on significant estimates and assumptions, including Level 3 inputs, which require judgment. Estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting risk inherent in future cash flows and future market prices. The excess of the purchase price over the estimated fair value of assets acquired and liabilities assumed was recognized as goodwill at the acquisition date. The goodwill arising from the acquisition consists largely of growth opportunities from the Texas pipeline business. Approximately $380 million of the goodwill is expected to be deductible for income tax purposes over a 15 year period. A liability of approximately $186 million was recognized as of the acquisition date for each of the contingent holdback and the indemnity holdback, reflecting the fair value of the expected future payments. NEE determined this fair value measurement based on management's probability assessment. The significant inputs and assumptions used in the fair value measurement included the estimated probability of executing contracts related to financial performance and capital expenditure thresholds as well as the appropriate discount rate. In 2016, NEE recorded fair value adjustments to eliminate the entire contingent holdback as the contracts contemplated in the acquisition were not executed by December 31, 2016 . The fair value adjustments are reflected as revaluation of contingent consideration in NEE's consolidated statements of income. At December 31, 2016 , the carrying amount of the indemnity holdback was approximately $ 199 million . The indemnity holdback is included in current other liabilities at December 31, 2016 and the contingent and indemnity holdbacks are included in noncurrent other liabilities at December 31, 2015 on NEE's consolidated balance sheets. The following table summarizes the estimated fair value of assets acquired and liabilities assumed for the acquisition of the Texas pipeline business: Amounts Recognized (millions) Assets: Property, plant and equipment $ 806 Cash 1 Other receivables and current other assets 21 Noncurrent other assets (other intangible assets, see Note 1 - Goodwill and Other Intangible Assets) 720 Noncurrent other assets (goodwill, see Note 1 - Goodwill and Other Intangible Assets) 622 Total assets $ 2,170 Liabilities: Long-term debt, including current portion $ 706 Accounts payable and current other liabilities 46 Noncurrent other liabilities, primarily acquisition holdbacks 415 Total liabilities 1,167 Less noncontrolling interest at fair value 69 Total cash consideration $ 934 Pending Oncor-Related Transactions - In July 2016, NEE, EFH Merger Co., LLC (Merger Sub), a direct wholly owned subsidiary of NEE, Energy Future Holdings Corp. (EFH Corp.) and Energy Future Intermediate Holding Company LLC (EFIH), a direct wholly owned subsidiary of EFH Corp., entered into an agreement and plan of merger (EFH merger agreement). Pursuant to the EFH merger agreement and after the reorganization of EFH Corp. (reorganized EFH) under the United States Bankruptcy Code, Merger Sub will acquire 100% of the equity of reorganized EFH Corp. and certain of its direct and indirect subsidiaries, including its indirect ownership of 80.03% of the outstanding equity interests of Oncor Electric Delivery Company LLC (Oncor), a regulated electric distribution and transmission business that operates the largest distribution and transmission system in Texas. The EFH merger agreement, as amended in September 2016, provides that the consideration for the transaction funded by NEE will be $9.796 billion , which will be paid almost all in cash, with the balance in shares of NEE common stock. The amount of consideration will be subject to adjustment as provided in the EFH merger agreement. On February 17, 2017, the U.S. Bankruptcy Court for the District of Delaware confirmed EFH Corp.'s Eighth Amended Joint Plan of Reorganization. Completion of the merger and the actual closing date remain subject to, among other things, approval by the Public Utility Commission of Texas (PUCT) and receipt of a supplemental private letter ruling from the Internal Revenue Service. NEE, Merger Sub, EFH Corp. and EFIH have certain specified termination rights under the EFH merger agreement. In October 2016, NEE and Oncor filed a joint application with the PUCT requesting the approval of the EFH Corp. merger, as well as the TTHC merger described below. The PUCT hearings regarding the merger transactions were conducted the week of February 20, 2017. In October 2016, NEE and its direct wholly owned subsidiary WSS Acquisition Company (TTHC Merger Sub) entered into an agreement (TTHC merger agreement) with Texas Transmission Holdings Corporation (TTHC) and certain stockholders of TTHC, Cheyne Walk Investment Pte Ltd, Borealis Power Holdings Inc. and BPC Health Corporation (together, the Primary Holders). Pursuant to the TTHC merger agreement, TTHC Merger Sub would merge with TTHC for a total cash merger consideration to be paid by NEE of approximately $2.410 billion , subject to adjustment as provided in the TTHC merger agreement. TTHC, through Texas Transmission Investment LLC (TTI), a wholly owned subsidiary, owns an approximately 20% interest in Oncor. Completion of the TTHC merger and actual closing date remain subject to, among other things, approval by the PUCT. NEE, TTHC Merger Sub, TTHC and the Primary Holders have certain specified termination rights under the TTHC merger agreement. In October 2016, T & D Equity Acquisition, LLC (OMI purchaser), a direct wholly owned subsidiary of NEE, Oncor Management Investment LLC (OMI) and Oncor entered into an agreement for the OMI purchaser to purchase OMI's 0.22% interest in Oncor for approximately $27 million . This transaction is subject to NEE closing its agreement to acquire EFH Corp. described above. The TTHC and OMI transactions, when combined with NEE’s agreement to acquire EFH Corp. described above, if completed, would result in NEE owning 100% of Oncor. NEE expects the EFH Corp. merger and the other Oncor-related transactions to be completed in the first half of 2017.

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2016
Variable Interest Entities [Abstract]
Variable Interest Entities	Variable Interest Entities (VIEs) In February 2015, the FASB issued an accounting standards update that modified consolidation guidance. The standards update makes changes to both the variable interest entity model and the voting interest entity model, including modifying the evaluation of whether limited partnerships or similar legal entities are VIEs or voting interest entities and amending the guidance for assessing how relationships of related parties affect the consolidation analysis of VIEs. The standards update was effective for NEE and FPL beginning January 1, 2016, and the modified retrospective approach was adopted. The adoption of the standards update did not result in any changes to the previous consolidation conclusions; however, it did result in a limited number of entities being considered VIEs and the related disclosure was provided for the current period. As of December 31, 2016 , NEE has thirty-three VIEs which it consolidates and has interests in certain other VIEs which it does not consolidate. FPL - FPL is considered the primary beneficiary of, and therefore consolidates, a VIE that is a wholly owned bankruptcy remote special purpose subsidiary that it formed in 2007 for the sole purpose of issuing storm-recovery bonds pursuant to the securitization provisions of the Florida Statutes and a financing order of the FPSC. FPL is considered the primary beneficiary because FPL has the power to direct the significant activities of the VIE, and its equity investment, which is subordinate to the bondholder's interest in the VIE, is at risk. Storm restoration costs incurred by FPL during 2005 and 2004 exceeded the amount in FPL's funded storm and property insurance reserve, resulting in a storm reserve deficiency. In 2007, the VIE issued $ 652 million aggregate principal amount of senior secured bonds (storm-recovery bonds), primarily for the after-tax equivalent of the total of FPL's unrecovered balance of the 2004 storm restoration costs, the 2005 storm restoration costs and to reestablish FPL's storm and property insurance reserve. In connection with this financing, net proceeds, after debt issuance costs, to the VIE (approximately $ 644 million ) were used to acquire the storm-recovery property, which includes the right to impose, collect and receive a storm-recovery charge from all customers receiving electric transmission or distribution service from FPL under rate schedules approved by the FPSC or under special contracts, certain other rights and interests that arise under the financing order issued by the FPSC and certain other collateral pledged by the VIE that issued the bonds. The storm-recovery bonds are payable only from and are secured by the storm-recovery property. The bondholders have no recourse to the general credit of FPL. The assets of the VIE were approximately $ 216 million and $ 230 million at December 31, 2016 and 2015 , respectively, and consisted primarily of storm-recovery property, which are included in both current and noncurrent regulatory assets on NEE's and FPL's consolidated balance sheets. The liabilities of the VIE were approximately $ 214 million and $ 278 million at December 31, 2016 and 2015 , respectively, and consisted primarily of storm-recovery bonds, which are included in long-term debt on NEE's and FPL's consolidated balance sheets. FPL entered into a purchased power agreement effective in 1995 with a 330 MW coal-fired facility to purchase substantially all of the facility's capacity and electrical output over a substantial portion of its estimated useful life. The facility is considered a VIE because FPL absorbs a portion of the facility's variability related to changes in the market price of coal through the price it pays per MWh (energy payment). Since FPL does not control the most significant activities of the facility, including operations and maintenance, FPL is not the primary beneficiary and does not consolidate this VIE. The energy payments paid by FPL will fluctuate as coal prices change. This fluctuation does not expose FPL to losses since the energy payments paid by FPL to the facility are recovered through the fuel clause as approved by the FPSC. See Note 13 - Contracts for a discussion of FPL's purchase of the 330 MW coal-fired facility. NEER - NEE consolidates thirty-two NEER VIEs. NEER is considered the primary beneficiary of these VIEs since NEER controls the most significant activities of these VIEs, including operations and maintenance, as well as construction, and has the obligation to absorb expected losses of these VIEs. A subsidiary of NEER is the primary beneficiary of, and therefore consolidates, NEP, which consolidates NEP OpCo because of NEP’s controlling interest in the general partner of NEP OpCo. NEP is a limited partnership formed to acquire, manage and own contracted clean energy projects with stable, long-term cash flows through a limited partner interest in NEP OpCo. NEE owns a controlling non-economic general partner interest in NEP and a limited partner interest in NEP OpCo, and presents NEP's limited partner interest as a noncontrolling interest in NEE's consolidated financial statements. At December 31, 2016 , NEE owns common units of NEP OpCo representing noncontrolling interest in NEP’s operating projects of approximately 65.2% . The assets and liabilities of NEP were approximately $ 7.2 billion and $ 5.0 billion , respectively, at December 31, 2016 , and primarily consisted of property, plant and equipment and long-term debt. A NEER VIE consolidates two entities which own and operate natural gas/oil electric generation facilities with the capability of producing 110 MW. These entities sell their electric output under power sales contracts to a third party, with expiration dates in 2018 and 2020 . The power sales contracts provide the offtaker the ability to dispatch the facilities and require the offtaker to absorb the cost of fuel. The entities have third-party debt which is secured by liens against the generation facilities and the other assets of these entities. The debt holders have no recourse to the general credit of NEER for the repayment of debt. The assets and liabilities of the VIE were approximately $ 95 million and $ 42 million , respectively, at December 31, 2016 and $ 84 million and $ 47 million , respectively, at December 31, 2015 , and consisted primarily of property, plant and equipment and long-term debt. Two indirect subsidiaries of NEER each contributed, to a NEP subsidiary, an approximately 50 % ownership interest in three entities which own and operate solar PV facilities with the capability of producing a total of approximately 277 MW. Each of the two indirect subsidiaries of NEER is considered a VIE since the non-managing members have no substantive rights over the managing members, and is consolidated by NEER. These three entities sell their electric output to third parties under power sales contracts with expiration dates in 2035 and 2036 . The three 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 NEER for the repayment of debt. The assets and liabilities of these VIEs were approximately $ 571 million and $ 487 million , respectively, at December 31, 2016 and $ 657 million and $ 626 million , respectively, at December 31, 2015 , and consisted primarily of property, plant and equipment and long-term debt. NEER consolidates a special purpose entity that has insufficient equity at risk and is considered a VIE. The entity provided a loan in the form of a note receivable (see Note 4 - Fair Value of Financial Instruments Recorded at Other than Fair Value) to an unrelated third party, and also issued senior secured bonds which are collateralized by the note receivable. The assets and liabilities of the VIE were approximately $502 million and $511 million , respectively, at December 31, 2016 , and consisted primarily of notes receivables (included in other investments) and long-term debt. The other twenty-seven NEER VIEs that are consolidated relate to certain subsidiaries which have sold differential membership interests in entities which own and operate wind electric generation and solar PV facilities with the capability of producing a total of approximately 6,847 MW and 374 MW, respectively. These entities sell their electric output either under power sales contracts to third parties with expiration dates ranging from 2018 through 2046 or in the spot market. Certain investors that have no equity at risk in the VIEs hold differential membership interests, which give them the right to receive a portion of the economic attributes of the generation facilities, including certain tax attributes. Certain entities have third-party debt which is secured by liens against the generation facilities and the other assets of these entities or by pledges of NEER's 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 $ 10.9 billion and $ 6.9 billion , respectively, at December 31, 2016 . Twenty of the twenty-seven were VIEs at December 31, 2015 and were consolidated; the assets and liabilities of those VIEs totaled approximately $ 7.6 billion and $ 5.0 billion , respectively, at December 31, 2015 . At December 31, 2016 and 2015 , the assets and liabilities of the VIEs consisted primarily of property, plant and equipment, deferral related to differential membership interests and long-term debt. Other - As of December 31, 2016 and 2015 , several NEE subsidiaries have investments totaling approximately $ 2,505 million ($ 2,049 million at FPL) and $ 602 million ($ 476 million at FPL), respectively, which are included in special use funds and other investments on NEE's consolidated balance sheets and in special use funds on FPL's consolidated balance sheets. At December 31, 2016 , these investments represented primarily commingled funds, and at December 31, 2015 , mortgage-backed securities. NEE subsidiaries, including FPL, are not the primary beneficiary 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. These entities are limited partnerships or similar entity structures in which the limited partners or nonmanaging members do not have substantive rights, 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 $ 234 million at December 31, 2016 , which are included in other investments on NEE’s consolidated balance sheets. Subsidiaries of NEE have committed to invest an additional approximately $ 30 million in two of the entities.

Investments in Partnerships and

Investments in Partnerships and Joint Ventures	12 Months Ended
	Dec. 31, 2016
Investments in Partnerships and Joint Ventures [Abstract]
Investments in Partnerships and Joint Ventures	Investments in Partnerships and Joint Ventures Certain subsidiaries of NEE, primarily NEER, have noncontrolling non-majority owned interests in various partnerships and joint ventures, essentially all of which are in the process of developing or constructing natural gas pipelines or own electric generation facilities. At December 31, 2016 and 2015 , NEE's investments in partnerships and joint ventures totaled approximately $1,767 million and $1,063 million , respectively, which are included in other investments on NEE's consolidated balance sheets. NEER's interest in these partnerships and joint ventures primarily range from approximately 31% to 50% . At December 31, 2016 and 2015, the principal entities included in NEER's investments in partnerships and joint ventures were Sabal Trail Transmission, LLC, Desert Sunlight Investment Holdings, LLC, Northeast Energy, LP and Cedar Point II Wind, LP. Summarized combined information for these principal entities is as follows: 2016 2015 (millions) Net income $ 264 $ 213 Total assets $ 4,502 $ 3,339 Total liabilities $ 1,364 $ 1,307 Partners'/members' equity $ 3,138 $ 2,032 NEER's share of underlying equity in the principal entities $ 1,423 $ 874 Difference between investment carrying amount and underlying equity in net assets (a) 65 (3 ) NEER's investment carrying amount for the principal entities $ 1,488 $ 871 ______________________ (a) Substantially all of the difference between the investment carrying amount and the underlying equity in net assets is being amortized over a 25-year period. In 2004, a trust created by NEE sold $ 300 million of 5 7/8% preferred trust securities to the public and $ 9 million of common trust securities to NEE. The trust is an unconsolidated 100% -owned finance subsidiary. The proceeds from the sale of the preferred and common trust securities were used to buy 5 7/8% junior subordinated debentures maturing in March 2044 from NEECH. NEE has fully and unconditionally guaranteed the preferred trust securities and the junior subordinated debentures.

Common Shareholders' Equity

Common Shareholders' Equity	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Common Shareholders' Equity	Common Shareholders' Equity Stock-Based Compensation - On March 30, 2016, the FASB issued an accounting standards update related to the accounting for employee share-based payment awards including simplification in areas such as (i) income tax consequences; (ii) classification of awards as either equity or liabilities; and (iii) classification on the statement of cash flows. The standards update was effective for NEE beginning January 1, 2017, however, NEE early adopted the provisions of the standards update during the three months ended June 30, 2016 with an effective date of January 1, 2016. Upon adoption, NEE recorded approximately $18 million primarily related to previously unrecognized excess tax benefits in deferred income taxes with a resulting increase to retained earnings as of January 1, 2016. For the year ended December 31, 2016, the impact of the standards update resulted in approximately $30 million of excess tax benefits being recorded in NEE's consolidated statements of income. All other provisions of the standards update did not have a material impact to NEE's consolidated financial statements. The standards update had no effect on FPL. Earnings Per Share - The reconciliation of NEE's basic and diluted earnings per share attributable to NEE is as follows: Years Ended December 31, 2016 2015 2014 (millions, except per share amounts) Numerator - net income attributable to NEE $ 2,912 $ 2,752 $ 2,465 Denominator: Weighted-average number of common shares outstanding - basic 463.1 450.5 434.4 Equity units, performance share awards, stock options, forward sale agreement and restricted stock (a) 2.7 3.5 5.7 Weighted-average number of common shares outstanding - assuming dilution 465.8 454.0 440.1 Earnings per share attributable to NEE: Basic $ 6.29 $ 6.11 $ 5.67 Assuming dilution $ 6.25 $ 6.06 $ 5.60 ______________________ (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, performance share awards, stock options and forward sale agreements and restricted stock which were not included in the denominator above due to their antidilutive effect were approximately 7.9 million , 3.5 million and 2.6 million for the years ended December 31, 2016 , 2015 and 2014 , respectively. Issuance of Common Stock and Forward Sale Agreement - In November 2013, NEE sold 4.5 million shares of its common stock at a price of $88.03 per share, and a forward counterparty borrowed and sold 6.6 million shares of NEE's common stock in connection with a forward sale agreement. In December 2014, NEE physically settled the forward sale agreement by delivering 6.6 million shares of its common stock to the forward counterparty in exchange for cash proceeds of approximately $552 million . The forward sale price used to determine the cash proceeds received by NEE was calculated based on the initial forward sale price of $88.03 per share less certain adjustments as specified in the forward sale agreement. Prior to the settlement date, the forward sale agreement had a dilutive effect on NEE’s earnings per share when the average market price per share of NEE’s common stock was above the adjusted forward sale price per share. Forward Sale Agreements - In November 2016, NEE entered into forward sale agreements with several forward counterparties to be settled on a date or dates to be specified at NEE’s direction, no later than November 1, 2017. NEE may elect physical settlement, cash settlement or net share settlement for all or a portion of its obligations under the forward sale agreements. If NEE physically settles, it will deliver the shares of its common stock to the applicable forward counterparty in exchange for cash proceeds at the then applicable forward sale price, which represents the initial forward sale price of $124.00 per share, less certain adjustments as specified in the forward sale agreements. The forward sale transactions are classified as equity transactions because they are indexed to NEE's common stock and physical settlement is within NEE's control. At December 31, 2016, if NEE had settled the forward sale agreements by delivery of 12 million shares of its common stock to the forward counterparties, NEE would have received net proceeds of approximately $1.5 billion . Prior to the settlement date, the forward sale agreements will have a dilutive effect on NEE's earnings per share when the average market price per share of NEE's common stock is above the adjusted forward sale price per share. As of December 31, 2016, the adjusted forward sale price per share was greater than the average market price per share of NEE's common stock; accordingly the 12 million shares were antidilutive. 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, 2016 , 2015 and 2014 includes approximately $ 77 million , $ 60 million and $ 60 million , respectively, of compensation costs and $ 30 million , $ 23 million and $ 23 million , respectively, of income tax benefits related to stock-based compensation arrangements. Compensation cost capitalized for the years ended December 31, 2016 , 2015 and 2014 was not material. As of December 31, 2016 , there were approximately $ 78 million of unrecognized compensation costs related to nonvested/nonexercisable stock-based compensation arrangements. These costs are expected to be recognized over a weighted-average period of 1.8 years. At December 31, 2016 , approximately 16 million shares of common stock were authorized for awards to officers, employees and non-employee directors of NEE and its subsidiaries under NEE's: (a) Amended and Restated 2011 Long Term Incentive Plan, (b) 2007 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 of performance share awards is estimated primarily 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, 2016 was as follows: Shares Weighted- Average Grant Date Fair Value Per Share Restricted Stock: Nonvested balance, January 1, 2016 563,660 $ 89.60 Granted 291,422 $ 112.86 Vested (274,144 ) $ 85.62 Forfeited (24,290 ) $ 100.78 Nonvested balance, December 31, 2016 556,648 $ 103.26 Performance Share Awards: Nonvested balance, January 1, 2016 915,199 $ 81.90 Granted 604,686 $ 89.23 Vested (630,773 ) $ 69.40 Forfeited (54,679 ) $ 95.62 Nonvested balance, December 31, 2016 834,433 $ 95.76 The weighted-average grant date fair value per share of restricted stock granted for the years ended December 31, 2015 and 2014 was $ 103.58 and $ 93.46 respectively. The weighted-average grant date fair value per share of performance share awards granted for the years ended December 31, 2015 and 2014 was $ 77.12 and $ 71.52 , respectively. The total fair value of restricted stock and performance share awards vested was $ 99 million , $ 108 million and $ 85 million for the years ended December 31, 2016 , 2015 and 2014 , 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: 2016 2015 2014 Expected volatility (a) 16.37% 18.91% 20.32% Expected dividends 3.16% 3.11% 3.11% Expected term (years) (b) 7.0 7.0 7.0 Risk-free rate 1.50% 1.84% 2.17% ______________________ (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, 2016 was as follows: Shares Underlying Options Weighted- Average Exercise Price Per Share Weighted- Average Remaining Contractual Term (years) Aggregate Intrinsic Value (millions) Balance, January 1, 2016 2,866,501 $ 63.39 Granted 294,889 $ 111.67 Exercised (651,492 ) $ 55.37 Forfeited (4,690 ) $ 106.64 Balance, December 31, 2016 2,505,208 $ 71.08 5.4 $ 121 Exercisable, December 31, 2016 2,043,899 $ 62.90 4.7 $ 116 The weighted-average grant date fair value of options granted was $ 11.74 , $ 13.62 and $ 14.09 per share for the years ended December 31, 2016 , 2015 and 2014 , respectively. The total intrinsic value of stock options exercised was approximately $ 42 million , $ 11 million and $ 30 million for the years ended December 31, 2016 , 2015 and 2014 , respectively. Cash received from option exercises was approximately $ 36 million , $ 9 million and $ 26 million for the years ended December 31, 2016 , 2015 and 2014 , respectively. The tax benefits realized from options exercised were approximately $16 million , $ 4 million and $ 11 million for the years ended December 31, 2016 , 2015 and 2014 , respectively. Preferred Stock - NEE's charter authorizes the issuance of 100 million shares of serial preferred stock, $ 0.01 par value, none of which are outstanding. FPL's charter authorizes the issuance of 10,414,100 shares of preferred stock, $ 100 par value, 5 million shares of subordinated preferred stock, no par value, and 5 million shares of preferred stock, no par value, none of which are outstanding. Accumulated Other Comprehensive Income (Loss) - The components of AOCI, net of tax, are as follows: Accumulated Other Comprehensive Income (Loss) Net Unrealized Gains (Losses) on Cash Flow Hedges Net Unrealized Gains (Losses) on Available for Sale Securities Defined Benefit Pension and Other Benefits Plans Net Unrealized Losses on Foreign Currency Translation Other Comprehensive Income (Loss) Related to Equity Method Investee Total (millions) Balances, December 31, 2013 $ (115 ) $ 197 $ 23 $ (33 ) $ (16 ) $ 56 Other comprehensive income (loss) before reclassifications (141 ) 62 (44 ) (25 ) (8 ) (156 ) Amounts reclassified from AOCI 98 (a) (41 ) (b) 1 — — 58 Net other comprehensive income (loss) (43 ) 21 (43 ) (25 ) (8 ) (98 ) Less other comprehensive loss attributable to noncontrolling interests (2 ) — — — — (2 ) Balances, December 31, 2014 (156 ) 218 (20 ) (58 ) (24 ) (40 ) Other comprehensive loss before reclassifications (88 ) (7 ) (42 ) (27 ) — (164 ) Amounts reclassified from AOCI 63 (a) (37 ) (b) — — — 26 Net other comprehensive loss (25 ) (44 ) (42 ) (27 ) — (138 ) Less other comprehensive loss attributable to noncontrolling interests (11 ) — — — — (11 ) Balances, December 31, 2015 (170 ) 174 (62 ) (85 ) (24 ) (167 ) Other comprehensive income (loss) before reclassifications — 69 (21 ) (5 ) 2 45 Amounts reclassified from AOCI 70 (a) (18 ) (b) — — — 52 Net other comprehensive income (loss) 70 51 (21 ) (5 ) 2 97 Less other comprehensive income attributable to noncontrolling interests — — — — — — Balances, December 31, 2016 $ (100 ) $ 225 $ (83 ) $ (90 ) $ (22 ) $ (70 ) ———————————— (a) Reclassified to interest expense and also to other - net in 2014 and 2015 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.

Debt

Debt	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Debt	Debt Long-term debt consists of the following: December 31, 2016 2015 Maturity Balance Weighted- Balance Weighted- (millions) (millions) FPL: First mortgage bonds - fixed 2017 - 2044 $ 8,690 4.78 % $ 8,690 4.77 % Storm-recovery bonds - fixed (a) 2021 210 5.26 % 273 5.26 % Pollution control, solid waste disposal and industrial development revenue bonds - variable (b) 2020 - 2046 778 0.77 % 718 0.04 % Other long-term debt - variable (c) 2018 - 2019 450 1.66 % 400 1.11 % Other long-term debt - fixed 2016 - 2040 52 5.09 % 53 5.06 % Unamortized debt issuance costs and discount (108 ) (114 ) Total long-term debt of FPL 10,072 10,020 Less current maturities of long-term debt 367 64 Long-term debt of FPL, excluding current maturities 9,705 9,956 NEECH: Debentures - fixed (d) 2017 - 2023 4,100 2.87 % 3,100 3.15 % Debentures, related to NEE's equity units - fixed 2018 - 2021 2,200 1.88 % 1,200 1.98 % Junior subordinated debentures - primarily fixed (d) 2044 - 2076 3,460 5.40 % 2,978 5.84 % Japanese yen denominated senior notes - fixed (d) 2030 85 5.13 % 83 5.13 % Japanese yen denominated term loans - variable (c)(d) 2017 470 1.83 % 456 1.83 % Other long-term debt - fixed 2016 - 2044 924 2.45 % 1,307 4.55 % Other long-term debt - variable (c) 2016 - 2019 60 (e) 1.77 % 1,513 1.81 % Fair value hedge adjustment 8 24 Unamortized debt issuance costs and discount (101 ) (94 ) Total long-term debt of NEECH 11,206 10,567 Less current maturities of long-term debt 1,724 667 Long-term debt of NEECH, excluding current maturities 9,482 9,900 NEER: Senior secured limited-recourse bonds and notes - fixed 2017 - 2038 2,091 (f) 6.00 % 2,203 5.88 % Senior secured limited-recourse term loans - primarily variable (c)(d) 2016 - 2035 4,959 2.78 % 3,969 (g) 2.51 % Other long-term debt - primarily variable (c)(d) 2016 - 2040 2,262 2.97 % 2,273 2.72 % Unamortized debt issuance costs and premium - net (168 ) (131 ) Total long-term debt of NEER 9,144 8,314 Less current maturities of long-term debt 513 1,489 (h) Long-term debt of NEER, excluding current maturities 8,631 6,825 Total long-term debt $ 27,818 $ 26,681 ______________________ (a) Principal on the storm-recovery bonds is due on the final maturity date (the date by which the principal must be repaid to prevent a default) for each tranche, however, it is being paid semiannually and sequentially. (b) Tax exempt bonds that permit individual bond holders to tender the bonds for purchase at any time prior to maturity. In the event 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 the tax exempt bonds. As of December 31, 2016 , all tax exempt bonds tendered for purchase have been successfully remarketed. FPL's bank revolving line of credit facilities are available to support the purchase of tax exempt bonds. Variable interest rate is established at various intervals by the remarketing agent. (c) Variable rate is based on an underlying index plus a margin. (d) Interest rate contracts, primarily swaps, have been entered into with respect to certain of these debt issuances. Additionally, a foreign currency swap has been entered into with respect to the Japanese yen denominated term loans - variable. See Note 3. (e) Excludes debt totaling $373 million reflected in liabilities associated with assets held for sale on NEE's consolidated balance sheets. (f) Includes approximately $490 million of debt held by a wholly owned subsidiary of NEER and collateralized by a third-party note receivable held by that subsidiary. See Note 8 - NEER. (g) Excludes debt totaling $938 million reflected in liabilities associated with assets held for sale on NEE's consolidated balance sheets. See Note 1 - Assets and Liabilities Associated with Assets Held for Sale. (h) See Spain Solar Projects Debt Restructuring below. Minimum annual maturities of long - term debt for NEE are approximately $2,604 million , $2,118 million , $2,606 million , $1,842 million and $2,712 million for 2017 , 2018 , 2019 , 2020 and 2021 , respectively. The respective amounts for FPL are approximately $367 million , $347 million , $251 million , $10 million and $47 million . At December 31, 2016 and 2015 , short-term borrowings had a weighted-average interest rate of 1.07% ( 1.07% for FPL) and 2.10% ( 0.83% for FPL), respectively. Subsidiaries of NEE, including FPL, had credit facilities with available capacity as of December 31, 2016 of approximately $10.2 billion ( $3.6 billion for FPL), of which approximately $9.8 billion ( $3.6 billion for FPL) relate to revolving line of credit facilities and $0.4 billion ( none for FPL) relate to letter of credit facilities. Certain of the revolving line of credit facilities provide for the issuance of letters of credit of up to approximately $3.4 billion ( $0.7 billion for FPL). The issuance of letters of credit under certain revolving line of credit facilities is subject to the aggregate commitment of the relevant banks to issue letters of credit under the applicable facility. In February 2017, NEECH entered into two variable rate bi-lateral term loan agreements each providing for a $3.75 billion short-term, non-revolving term loan facility, for a total of $7.5 billion . The obligation to make loans pursuant to these bi-lateral term loan agreements terminates in August 2017 and each loan agreement expires in February 2018. There are currently no amounts outstanding under these facilities. 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 NEER and its subsidiaries. In May 2015, NEECH completed a remarketing of $600 million aggregate principal amount of its Series E Debentures due June 1, 2017 (Debentures) that were issued in May 2012 as components of equity units issued concurrently by NEE (May 2012 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 1.586% per year, and interest is payable on June 1 and December 1 of each year, commencing June 1, 2015. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the May 2012 equity units, on June 1, 2015, NEE issued 7,860,000 shares of common stock in exchange for $600 million . In August 2015, NEECH completed a remarketing of approximately $650 million aggregate principal amount of its Series F Debentures due September 1, 2017, which constitutes a portion of the $650 million aggregate principal amount of such debentures (Debentures) that were issued in September 2012 as components of equity units issued concurrently by NEE (September 2012 equity units). The Debentures are fully and unconditionally guaranteed by NEE. In connection with the remarketing of the Debentures, the interest rate on all of the Debentures was reset to 2.056% per year and interest is payable on March 1 and September 1 of each year, commencing September 1, 2015. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the September 2012 equity units, in August and September 2015, NEE issued a total of 8,173,099 shares of common stock in exchange for $650 million . In September 2015, NEE sold $700 million 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 H Debenture due September 1, 2020 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, 2018 (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 of $95.35 to $114.42 . If purchased on the final settlement date, as of December 31, 2016 , the number of shares issued would (subject to antidilution adjustments) range from 0.5261 shares if the applicable market value of a share of common stock is less than or equal to $95.35 to 0.4385 shares if the applicable market value of a share is equal to or greater than $114.42 , with applicable market value to be determined using the average closing prices of NEE common stock over a 20 -day trading period ending August 29, 2018. Total annual distributions on the equity units will be at the rate of 6.371% , consisting of interest on the debentures ( 2.36% per year) and payments under the stock purchase contracts ( 4.011% per year). The interest rate on the debentures is expected to be reset on or after March 1, 2018. 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 August 2016, NEE sold $1.5 billion of equity units (initially consisting of Corporate Units). Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series I Debenture due September 1, 2021 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, 2019 (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 of $127.63 to $159.54 . If purchased on the final settlement date, as of December 31, 2016 , the number of shares issued would (subject to antidilution adjustments) range from 0.3918 shares if the applicable market value of a share of common stock is less than or equal to $127.63 to 0.3134 shares if the applicable market value of a share is equal to or greater than $159.54 , with applicable market value to be determined using the average closing prices of NEE common stock over a 20 -day trading period ending August 28, 2019. Total annual distributions on the equity units will be at the rate of 6.123% , consisting of interest on the debentures ( 1.65% per year) and payments under the stock purchase contracts ( 4.473% per year). The interest rate on the debentures is expected to be reset on or after March 1, 2019. 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 2016, NEECH completed a remarketing of $500 million aggregate principal amount of its Series G Debentures due September 1, 2018 (Debentures) that were issued in September 2013 as components of equity units issued concurrently by NEE (September 2013 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 1.649% per year, and interest is payable on March 1 and September 1 of each year, commencing March 1, 2017. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the September 2013 equity units, on September 1, 2016, NEE issued 5,101,000 shares of common stock in exchange for $500 million . 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. Spain Solar Projects Debt Restructuring - In August 2016, NextEra Energy España, S.L., the NEER subsidiary in Spain that is the direct shareholder of the subsidiaries that own the solar projects in Spain (project-level subsidiaries), and the project-level subsidiaries entered into an agreement with the lenders to restructure the project-level debt, which included, among other things, a re-amortization of the debt, including extending the maturity date from 2030 to 2037, and reducing the original interest rate under the project-level financing agreements. At closing, the NEECH affiliates' remaining letter of credit posting obligation on behalf of the project-level subsidiaries of approximately €23 million (approximately $ 26 million ) was used primarily to make a prepayment of the restructured project-level debt. The noncurrent portions of the restructured project-level debt, net of unamortized debt issuance costs, and associated derivative liabilities related to the interest rate swaps were both reclassified from current to long-term debt and noncurrent derivative liabilities, respectively, on NEE's consolidated balance sheets as of December 31, 2016 and totaled approximately $ 498 million and $ 122 million , respectively, at that date. The restructured debt is secured solely by the assets of the project-level subsidiaries.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligations [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations FPL's AROs relate primarily to the nuclear decommissioning obligations of its nuclear units. FPL's AROs other than nuclear decommissioning obligations are not significant. The accounting provisions result in timing differences in the recognition of legal asset retirement costs for financial reporting purposes and the method the FPSC allows FPL to recover in rates. NEER's AROs relate primarily to the nuclear decommissioning obligations of its nuclear plants and obligations for the dismantlement of certain of its wind and solar facilities. See Note 1 - 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: FPL NEER NEE (millions) Balances, December 31, 2014 $ 1,355 $ 631 $ 1,986 Liabilities incurred 5 46 51 Accretion expense 73 43 116 Liabilities settled (20 ) (2 ) (22 ) Revision in estimated cash flows - net 409 (a) (71 ) (b) 338 Balances, December 31, 2015 1,822 647 2,469 Liabilities incurred 1 56 57 Accretion expense 91 47 138 Liabilities settled — (2 ) (2 ) Revision in estimated cash flows - net 5 69 (c) 74 Balances, December 31, 2016 $ 1,919 $ 817 $ 2,736 ______________________ (a) Primarily reflects the effect of revised cost estimates for decommissioning FPL's nuclear units consistent with the updated nuclear decommissioning studies approved by the FPSC. (b) Primarily reflects the effect of revised cost estimates for decommissioning NEER’s nuclear units and a change in assumptions relating to spent fuel costs, partly offset by increased escalation rates. (c) Primarily reflects the effect of revised cost estimates to dismantle certain of NEER’s wind and solar facilities. 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 as follows (see Note 4 - Special Use Funds): FPL NEER NEE (millions) Balances, December 31, 2016 $ 3,665 $ 1,769 $ 5,434 Balances, December 31, 2015 $ 3,430 $ 1,634 $ 5,064 NEE and FPL have identified but not recognized ARO liabilities related to electric transmission and distribution and telecommunications assets 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 ARO liability is not estimable for such easements as NEE and FPL intend to use these properties indefinitely. In the event NEE and FPL decide to abandon or cease the use of a particular easement, an ARO liability would be recorded at that time.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2016
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 or acquisition of additional facilities and equipment to meet customer demand, as well as capital improvements to and maintenance of existing facilities and the procurement of nuclear fuel. At NEER, capital expenditures include, among other things, the cost, including capitalized interest, for construction and development of wind and solar projects and the procurement of nuclear fuel, as well as the investment in the development and construction of its natural gas pipeline assets. Capital expenditures for Corporate and Other primarily include the cost to maintain existing transmission facilities at NextEra Energy Transmission, LLC . At December 31, 2016 , estimated capital expenditures for 2017 through 2021 for which applicable internal approvals (and also, if required, FPSC approvals for FPL or regulatory approvals for acquisitions) have been received were as follows: 2017 2018 2019 2020 2021 Total (millions) FPL: Generation: (a) New (b) $ 1,385 $ 655 $ 485 $ 35 $ 5 $ 2,565 Existing 1,240 635 680 645 600 3,800 Transmission and distribution 2,190 2,010 2,860 2,475 2,945 12,480 Nuclear fuel 125 190 170 210 120 815 General and other 440 275 285 220 330 1,550 Total $ 5,380 $ 3,765 $ 4,480 $ 3,585 $ 4,000 $ 21,210 NEER: Wind (c) $ 570 $ 955 $ 705 $ 75 $ 25 $ 2,330 Solar (d) 80 75 15 — — 170 Nuclear, including nuclear fuel 240 250 230 225 245 1,190 Natural gas pipelines (e) 890 845 50 20 10 1,815 Other 335 55 40 40 35 505 Total $ 2,115 $ 2,180 $ 1,040 $ 360 $ 315 $ 6,010 Corporate and Other $ 45 $ 30 $ 85 $ 55 $ 35 $ 250 ______________________ (a) Includes AFUDC of approximately $ 81 million , $ 79 million , $46 million and $6 million for 2017 through 2020, respectively. (b) Includes land, generation structures, transmission interconnection and integration and licensing. (c) Consists of capital expenditures for new wind projects, repowering of existing wind projects and related transmission totaling approximately 2,760 MW. (d) Includes capital expenditures for new solar projects and related transmission totaling approximately 225 MW. (e) Includes capital expenditures for construction of three natural gas pipelines, including equity contributions associated with equity investments in joint ventures for two pipelines and AFUDC associated with the third pipeline. The natural gas pipelines are subject to certain conditions. See Contracts below. The above estimates are subject to continuing review and adjustment and actual capital expenditures may vary significantly from these estimates. Contracts - In addition to the commitments made in connection with the estimated capital expenditures included in the table in Commitments above, FPL has commitments under long-term purchased power and fuel contracts. As of December 31, 2016 , FPL is obligated under a take-or-pay purchased power contract to pay for 375 MW annually through 2021 . FPL also has various firm pay-for-performance contracts to purchase approximately 114 MW from certain cogenerators and small power producers with expiration dates ranging from 2026 through 2034 . The purchased power contracts provide for capacity and energy payments. Energy payments are based on the actual power taken under these contracts. Capacity payments for the pay-for-performance contracts are subject to the facilities meeting certain contract conditions. FPL has contracts with expiration dates through 2036 for the purchase and transportation of natural gas and coal, and storage of natural gas. In addition, FPL has entered into 25 -year natural gas transportation agreements with each of Sabal Trail Transmission, LLC (Sabal Trail, an entity in which a wholly owned NEER subsidiary has a 42.5% ownership interest) and Florida Southeast Connection, LLC (Florida Southeast Connection, a wholly owned NEER subsidiary), each of which will build, own and operate a pipeline that will be part of a natural gas pipeline system, for a quantity of 400,000 MMBtu/day beginning mid-2017 and increasing to 600,000 MMBtu/day in mid-2020. These agreements contain firm commitments that are contingent upon the occurrence of certain events, including the completion of construction of the pipeline system to be built by Sabal Trail and Florida Southeast Connection. See Commitments above. As of December 31, 2016 , NEER has entered into contracts with expiration dates ranging from late February 2017 through 2032 primarily for the purchase of wind turbines, wind towers and solar modules and related construction and development activities, as well as for the supply of uranium, and the conversion, enrichment and fabrication of nuclear fuel and has made commitments for the construction of the natural gas pipelines. Approximately $3.1 billion of related commitments are included in the estimated capital expenditures table in Commitments above. In addition, NEER has contracts primarily for the purchase, transportation and storage of natural gas with expiration dates ranging from March 2017 through 2019 . The required capacity and/or minimum payments under the contracts discussed above as of December 31, 2016 were estimated as follows: 2017 2018 2019 2020 2021 Thereafter (millions) FPL: Capacity charges (a) $ 75 $ 65 $ 50 $ 20 $ 20 $ 250 Minimum charges, at projected prices: (b) Natural gas, including transportation and storage (c) $ 1,305 $ 900 $ 900 $ 910 $ 905 $ 12,065 Coal, including transportation $ 125 $ 5 $ 5 $ — $ — $ — NEER $ 1,385 $ 1,380 $ 140 $ 90 $ 75 $ 285 Corporate and Other (d)(e) $ 45 $ 10 $ — $ 5 $ — $ — ______________________ (a) Capacity charges, substantially all of which are recoverable through the capacity clause, totaled approximately $ 175 million , $ 434 million and $ 485 million for the years ended December 31, 2016, 2015 and 2014 , respectively. Energy charges, which are recoverable through the fuel clause, totaled approximately $ 126 million , $ 262 million and $ 299 million for the years ended December 31, 2016, 2015 and 2014 , respectively. (b) Recoverable through the fuel clause. (c) Includes approximately $ 200 million , $ 295 million , $ 290 million , $360 million , $390 million and $ 7,495 million in 2017, 2018, 2019, 2020, 2021 and thereafter, respectively, of firm commitments, subject to certain conditions as noted above, related to the natural gas transportation agreements with Sabal Trail and Florida Southeast Connection. (d) Includes an approximately $30 million commitment to invest in clean power and technology businesses primarily in 2017. (e) Excludes approximately $263 million and $148 million in 2017 and 2018, respectively, of joint obligations of NEECH and NEER which are included in the NEER amounts above. In January 2017, FPL assumed ownership of a 330 MW coal-fired generation facility located in Indiantown, Florida for a purchase price of $451 million (including existing debt of approximately $218 million ). FPL will record a regulatory asset for approximately $451 million , which will be amortized over nine years and recovered through the capacity clause with a return on the portion of the unamortized balance of the regulatory asset. Prior to assuming ownership of this facility, FPL had a long-term purchased power agreement with this facility for substantially all of its capacity and energy. FPL expects to reduce the plant’s operations with the intention of eventually phasing the plant out of service. FPL will recover the fuel costs of the facility through the fuel clause and operating costs through the capacity clause until FPL's next base rate filing where non-fuel cost recovery will be through base rates. Insurance - Liability for accidents at nuclear power plants is governed by the Price-Anderson Act, which limits the liability of nuclear reactor owners to the amount of insurance available from both private sources and an industry retrospective payment plan. In accordance with this Act, NEE maintains $ 450 million of private liability insurance per site, which is the maximum obtainable, and participates in a secondary financial protection system, which provides up to $ 13.0 billion of liability insurance coverage per incident at any nuclear reactor in the U.S. Under the secondary financial protection system, NEE is subject to retrospective assessments of up to $ 1.0 billion ($ 509 million for FPL), plus any applicable taxes, per incident at any nuclear reactor in the U.S., payable at a rate not to exceed $ 152 million ($ 76 million for FPL) per incident per year. NEE and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook, Duane Arnold and St. Lucie Unit No. 2, which approximates $ 15 million , $ 38 million and $ 19 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. 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 $ 186 million ($ 112 million for FPL), plus any applicable taxes, in retrospective premiums in a policy year. NEE and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook, Duane Arnold and St. Lucie Unit No. 2, which approximates $ 3 million , $ 5 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. Should FPL's future storm restoration costs exceed the reserve amount established through the issuance of storm-recovery bonds by a VIE in 2007, FPL may recover storm restoration costs, subject to prudence review by the FPSC, either through surcharges approved by the FPSC or through securitization provisions pursuant to Florida law. In February 2017, the FPSC approved FPL's request to recover through an interim surcharge the 2016 eligible storm restoration costs that exceeded the reserve amount. See Note 1 - Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve. 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, 2016
Segment Reporting [Abstract]
Segment Information	Segment Information NEE's reportable segments are FPL, a rate-regulated electric utility, and NEER, a competitive energy business. Corporate and Other represents other business activities and eliminating entries. NEE's operating revenues derived from the sale of electricity represented approximately 90% , 92% and 91% of NEE's operating revenues for the years ended December 31, 2016 , 2015 and 2014 , respectively. Approximately 2% of operating revenues were from foreign sources for each of the years ended December 31, 2016 , 2015 and 2014 . At each of December 31, 2016 and 2015 , approximately 3% of long-lived assets were located in foreign countries. NEE's segment information is as follows: 2016 2015 2014 FPL NEER (a) Corp. and Other NEE Consoli- dated FPL NEER (a) Corp. and Other NEE Consoli- dated FPL NEER (a) Corp. and Other NEE Consoli- dated (millions) Operating revenues $ 10,895 $ 4,893 $ 367 $ 16,155 $ 11,651 $ 5,444 $ 391 $ 17,486 $ 11,421 $ 5,196 $ 404 $ 17,021 Operating expenses - net $ 7,737 $ 3,419 $ 391 $ 11,547 $ 8,674 $ 3,865 $ 315 $ 12,854 $ 8,593 $ 3,727 $ 317 $ 12,637 Interest expense $ 456 $ 732 $ (95 ) $ 1,093 $ 445 $ 625 $ 141 $ 1,211 $ 439 $ 667 $ 155 $ 1,261 Interest income $ 2 $ 34 $ 46 $ 82 $ 7 $ 28 $ 51 $ 86 $ 3 $ 26 $ 51 $ 80 Depreciation and amortization $ 1,651 $ 1,366 $ 60 $ 3,077 $ 1,576 $ 1,183 $ 72 $ 2,831 $ 1,432 $ 1,051 $ 68 $ 2,551 Equity in earnings (losses) of equity method investees $ — $ 119 $ 29 $ 148 $ — $ 103 $ 4 $ 107 $ — $ 95 $ (2 ) $ 93 Income tax expense (benefit) (b) $ 1,051 $ 242 $ 90 $ 1,383 $ 957 $ 289 $ (18 ) $ 1,228 $ 910 $ 283 $ (17 ) $ 1,176 Net income (loss) $ 1,727 $ 1,218 $ 60 $ 3,005 $ 1,648 $ 1,102 $ 12 $ 2,762 $ 1,517 $ 993 $ (41 ) $ 2,469 Net income (loss) attributable to NEE $ 1,727 $ 1,125 $ 60 $ 2,912 $ 1,648 $ 1,092 $ 12 $ 2,752 $ 1,517 $ 989 $ (41 ) $ 2,465 Capital expenditures, independent power and other investments and nuclear fuel purchases $ 3,934 $ 5,521 $ 181 $ 9,636 $ 3,633 $ 4,661 $ 83 $ 8,377 $ 3,241 $ 3,701 $ 75 $ 7,017 Property, plant and equipment $ 48,313 $ 37,644 $ 1,056 $ 87,013 $ 45,383 $ 33,340 $ 1,607 $ 80,330 $ 41,938 $ 30,178 $ 1,523 $ 73,639 Accumulated depreciation and amortization $ 12,304 $ 7,655 $ 142 $ 20,101 $ 11,862 $ 6,640 $ 442 $ 18,944 $ 11,282 $ 6,268 $ 384 $ 17,934 Total assets $ 45,501 $ 41,743 $ 2,749 $ 89,993 $ 42,523 $ 37,647 $ 2,309 $ 82,479 $ 39,222 $ 32,896 $ 2,487 $ 74,605 Investment in equity method investees $ — $ 1,661 $ 106 $ 1,767 $ — $ 983 $ 80 $ 1,063 $ — $ 617 $ 46 $ 663 _________________________ (a) Interest expense allocated from NEECH is based on a deemed capital structure of 70% debt. For this purpose, the deferred credit associated with differential membership interests sold by NEER subsidiaries is included with debt. Residual NEECH corporate interest expense is included in Corporate and Other. (b) NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 - Income Taxes.

Summarized Financial Informatio

Summarized Financial Information of NEECH	12 Months Ended
	Dec. 31, 2016
Summarized Financial Information [Abstract]
Summarized Financial Information of NEECH	Summarized Financial Information of NEECH NEECH, a 100% owned subsidiary of NEE, provides funding for, and holds ownership interests in, NEE's operating subsidiaries other than FPL. NEECH’s debentures and junior subordinated debentures including those that were registered pursuant to the Securities Act of 1933, as amended, are fully and unconditionally guaranteed by NEE. Condensed consolidating financial information is as follows: Condensed Consolidating Statements of Income Year Ended Year Ended Year Ended NEE NEECH Other (a) NEE NEE NEECH Other (a) NEE NEE NEECH Other (a) NEE (millions) Operating revenues $ — $ 5,283 $ 10,872 $ 16,155 $ — $ 5,849 $ 11,637 $ 17,486 $ — $ 5,614 $ 11,407 $ 17,021 Operating expenses - net (20 ) (3,663 ) (7,864 ) (11,547 ) (17 ) (4,142 ) (8,695 ) (12,854 ) (19 ) (4,039 ) (8,579 ) (12,637 ) Interest expense (1 ) (636 ) (456 ) (1,093 ) (4 ) (764 ) (443 ) (1,211 ) (6 ) (819 ) (436 ) (1,261 ) Equity in earnings of subsidiaries 2,956 — (2,956 ) — 2,754 — (2,754 ) — 2,494 — (2,494 ) — Other income - net 5 793 75 873 1 498 70 569 1 487 34 522 Income (loss) before income taxes 2,940 1,777 (329 ) 4,388 2,734 1,441 (185 ) 3,990 2,470 1,243 (68 ) 3,645 Income tax expense (benefit) 28 354 1,001 1,383 (18 ) 299 947 1,228 5 262 909 1,176 Net income (loss) 2,912 1,423 (1,330 ) 3,005 2,752 1,142 (1,132 ) 2,762 2,465 981 (977 ) 2,469 Less net income attributable to noncontrolling interests — 93 — 93 — 10 — 10 — 4 — 4 Net income (loss) attributable to NEE $ 2,912 $ 1,330 $ (1,330 ) $ 2,912 $ 2,752 $ 1,132 $ (1,132 ) $ 2,752 $ 2,465 $ 977 $ (977 ) $ 2,465 ______________________ (a) Represents primarily FPL and consolidating adjustments. Condensed Consolidating Statements of Comprehensive Income Year Ended Year Ended Year Ended NEE NEECH Other (a) NEE NEE NEECH Other (a) NEE NEE NEECH Other (a) NEE (millions) Comprehensive income (loss) attributable to NEE $ 3,009 $ 1,448 $ (1,448 ) $ 3,009 $ 2,625 $ 1,049 $ (1,049 ) $ 2,625 $ 2,369 $ 924 $ (924 ) $ 2,369 ______________________ (a) Represents primarily FPL and consolidating adjustments. Condensed Consolidating Balance Sheets December 31, 2016 December 31, 2015 NEE (Guaran- NEECH Other (a) NEE NEE (Guaran- NEECH Other (a) NEE (millions) PROPERTY, PLANT AND EQUIPMENT Electric plant in service and other property $ 28 $ 38,671 $ 48,314 $ 87,013 $ 27 $ 34,921 $ 45,382 $ 80,330 Accumulated depreciation and amortization (18 ) (7,778 ) (12,305 ) (20,101 ) (16 ) (7,067 ) (11,861 ) (18,944 ) Total property, plant and equipment - net 10 30,893 36,009 66,912 11 27,854 33,521 61,386 CURRENT ASSETS Cash and cash equivalents 1 1,258 33 1,292 — 546 25 571 Receivables 88 1,615 736 2,439 90 1,510 665 2,265 Other 2 1,877 1,799 3,678 4 2,443 1,512 3,959 Total current assets 91 4,750 2,568 7,409 94 4,499 2,202 6,795 OTHER ASSETS Investment in subsidiaries 24,323 — (24,323 ) — 22,544 — (22,544 ) — Other 867 8,992 5,813 15,672 823 7,790 5,685 14,298 Total other assets 25,190 8,992 (18,510 ) 15,672 23,367 7,790 (16,859 ) 14,298 TOTAL ASSETS $ 25,291 $ 44,635 $ 20,067 $ 89,993 $ 23,472 $ 40,143 $ 18,864 $ 82,479 CAPITALIZATION Common shareholders' equity $ 24,341 $ 7,699 $ (7,699 ) $ 24,341 $ 22,574 $ 6,990 $ (6,990 ) $ 22,574 Noncontrolling interests — 990 — 990 — 538 — 538 Long-term debt — 18,112 9,706 27,818 — 16,725 9,956 26,681 Total capitalization 24,341 26,801 2,007 53,149 22,574 24,253 2,966 49,793 CURRENT LIABILITIES Debt due within one year — 2,237 785 3,022 — 2,786 220 3,006 Accounts payable 1 2,668 778 3,447 4 1,919 606 2,529 Other 231 2,624 1,595 4,450 252 3,003 1,317 4,572 Total current liabilities 232 7,529 3,158 10,919 256 7,708 2,143 10,107 OTHER LIABILITIES AND DEFERRED CREDITS Asset retirement obligations — 816 1,920 2,736 — 647 1,822 2,469 Deferred income taxes 82 3,002 8,017 11,101 157 2,396 7,274 9,827 Other 636 6,487 4,965 12,088 485 5,139 4,659 10,283 Total other liabilities and deferred credits 718 10,305 14,902 25,925 642 8,182 13,755 22,579 COMMITMENTS AND CONTINGENCIES TOTAL CAPITALIZATION AND LIABILITIES $ 25,291 $ 44,635 $ 20,067 $ 89,993 $ 23,472 $ 40,143 $ 18,864 $ 82,479 ______________________ (a) Represents primarily FPL and consolidating adjustments. Condensed Consolidating Statements of Cash Flows Year Ended Year Ended Year Ended NEE (Guar- antor) NEECH Other (a) NEE Consoli- dated NEE (Guar- antor) NEECH Other (a) NEE Consoli- dated NEE (Guar- antor) NEECH Other (a) NEE Consoli- dated (millions) NET CASH PROVIDED BY OPERATING ACTIVITIES $ 1,897 $ 2,171 $ 2,268 $ 6,336 $ 1,659 $ 2,488 $ 1,969 $ 6,116 $ 1,615 $ 1,976 $ 1,909 $ 5,500 CASH FLOWS FROM INVESTING ACTIVITIES Capital expenditures, independent power and other investments and nuclear fuel purchases (1 ) (5,701 ) (3,934 ) (9,636 ) — (4,744 ) (3,633 ) (8,377 ) (1 ) (3,741 ) (3,275 ) (7,017 ) Capital contributions from NEE (745 ) — 745 — (1,480 ) — 1,480 — (912 ) — 912 — Cash grants under the Recovery Act — 335 — 335 — 8 — 8 — 343 — 343 Sale of independent power and other investments of NEER — 658 — 658 — 52 — 52 — 307 — 307 Proceeds from sale or maturity of securities in special use funds and other investments — 1,281 2,495 3,776 — 1,120 3,731 4,851 — 1,272 3,349 4,621 Purchases of securities in special use funds and other investments — (1,323 ) (2,506 ) (3,829 ) — (1,190 ) (3,792 ) (4,982 ) — (1,321 ) (3,446 ) (4,767 ) Proceeds from the sale of a noncontrolling interest in subsidiaries — 645 — 645 — 345 — 345 — 438 — 438 Other - net — (40 ) (19 ) (59 ) — 106 (8 ) 98 10 (64 ) (232 ) (286 ) Net cash used in investing activities (746 ) (4,145 ) (3,219 ) (8,110 ) (1,480 ) (4,303 ) (2,222 ) (8,005 ) (903 ) (2,766 ) (2,692 ) (6,361 ) CASH FLOWS FROM FINANCING ACTIVITIES Issuances of long-term debt — 5,349 308 5,657 — 4,689 1,083 5,772 — 4,057 997 5,054 Retirements of long-term debt — (3,048 ) (262 ) (3,310 ) — (3,421 ) (551 ) (3,972 ) — (4,395 ) (355 ) (4,750 ) Proceeds from differential membership investors — 1,859 — 1,859 — 761 — 761 — 978 — 978 Proceeds from other short-term debt — — 500 500 — 1,125 100 1,225 — 500 — 500 Repayments of other short-term debt — (212 ) (450 ) (662 ) — (813 ) — (813 ) — (500 ) — (500 ) Net change in commercial paper — (318 ) 212 (106 ) — 318 (1,086 ) (768 ) — (487 ) 938 451 Issuances of common stock - net 537 — — 537 1,298 — — 1,298 633 — — 633 Dividends on common stock (1,612 ) — — (1,612 ) (1,385 ) — — (1,385 ) (1,261 ) — — (1,261 ) Dividends to NEE — (650 ) 650 — — (698 ) 698 — — 812 (812 ) — Other - net (75 ) (294 ) 1 (368 ) (92 ) (162 ) 19 (235 ) (84 ) (31 ) 10 (105 ) Net cash provided by (used in) financing activities (1,150 ) 2,686 959 2,495 (179 ) 1,799 263 1,883 (712 ) 934 778 1,000 Net increase (decrease) in cash and cash equivalents 1 712 8 721 — (16 ) 10 (6 ) — 144 (5 ) 139 Cash and cash equivalents at beginning of year — 546 25 571 — 562 15 577 — 418 20 438 Cash and cash equivalents at end of year $ 1 $ 1,258 $ 33 $ 1,292 $ — $ 546 $ 25 $ 571 $ — $ 562 $ 15 $ 577 ______________________ (a) Represents primarily FPL and consolidating adjustments.

Quarterly Data (Unaudited)

Quarterly Data (Unaudited)	12 Months Ended
	Dec. 31, 2016
Quarterly Data (Unaudited) [Abstract]
Quarterly Data (Unaudited)	Quarterly Data (Unaudited) Condensed consolidated quarterly financial information is as follows: March 31 (a) June 30 (a) September 30 (a) December 31 (a) (millions, except per share amounts) NEE: 2016 Operating revenues (b) $ 3,835 $ 3,817 $ 4,805 $ 3,699 Operating income (b) $ 1,234 $ 1,169 $ 1,279 $ 926 Net income (b) $ 654 (c) $ 544 $ 789 $ 1,017 Net income attributable to NEE (b) $ 653 (c) $ 540 $ 753 $ 966 Earnings per share attributable to NEE - basic (d) $ 1.42 (c) $ 1.17 $ 1.63 $ 2.07 Earnings per share attributable to NEE - assuming dilution (d) $ 1.41 (c) $ 1.16 $ 1.62 $ 2.06 Dividends per share $ 0.87 $ 0.87 $ 0.87 $ 0.87 High-low common stock sales prices $119.37 - $102.20 $130.43 - $112.44 $131.98 - $120.22 $128.46 - $110.49 2015 Operating revenues (b) $ 4,104 $ 4,358 $ 4,954 $ 4,069 Operating income (b) $ 1,129 $ 1,146 $ 1,481 $ 876 Net income (b) $ 650 $ 720 $ 882 $ 510 Net income attributable to NEE (b) $ 650 $ 716 $ 879 $ 507 Earnings per share attributable to NEE - basic (d) $ 1.47 $ 1.61 $ 1.94 $ 1.10 Earnings per share attributable to NEE - assuming dilution (d) $ 1.45 $ 1.59 $ 1.93 $ 1.10 Dividends per share $ 0.77 $ 0.77 $ 0.77 $ 0.77 High-low common stock sales prices $112.64 - $97.48 $106.63 - $97.23 $109.98 - $93.74 $105.85 - $95.84 FPL: 2016 Operating revenues (b) $ 2,303 $ 2,750 $ 3,283 $ 2,558 Operating income (b) $ 714 $ 828 $ 921 $ 694 Net income (b) $ 393 $ 448 $ 515 $ 371 2015 Operating revenues (b) $ 2,541 $ 2,996 $ 3,274 $ 2,839 Operating income (b) $ 667 $ 780 $ 855 $ 674 Net income (b) $ 359 $ 435 $ 489 $ 365 ______________________ (a) In the opinion of NEE and FPL management, all adjustments, which consist of normal recurring accruals necessary to present a fair statement of the amounts shown for such periods, have been made. Results of operations for an interim period generally will not give a true indication of results for the year. (b) The sum of the quarterly amounts may not equal the total for the year due to rounding. (c) Amounts were restated to reflect the adoption in the second quarter of 2016 of an accounting standards update resulting in an increase to net income and net income attributable to NEE of $17 million , and an increase to earnings per share attributable to NEE, basic and assuming dilution, of $0.04 . See Note 10 - Stock-Based Compensation. (d) The sum of the quarterly amounts may not equal the total for the year due to rounding and changes in weighted-average number of common shares outstanding.

Summary of Significant Accoun26

Summary of Significant Accounting and Reporting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
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 (NEER), a wholly owned indirect subsidiary. FPL, a rate-regulated electric utility, supplies electric service to approximately 4.9 million customer accounts throughout most of the east and lower west coasts of Florida. NEER invests in independent power projects through both controlled and consolidated entities and noncontrolling ownership interests in joint ventures essentially all of which are accounted for under the equity method. NEER also participates in natural gas, natural gas liquids and oil production primarily through non-operating ownership interests and in pipeline infrastructure through either wholly owned subsidiaries or noncontrolling or joint venture interests. The consolidated financial statements of NEE and FPL include the accounts of their respective majority-owned and controlled subsidiaries. Intercompany balances and transactions have been eliminated in consolidation. Certain amounts included in prior years' consolidated financial statements have been reclassified to conform to the current year's presentation. The preparation of financial statements requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ from those estimates.
NextEra Energy Partners, LP	NextEra Energy Partners, LP - NEE, through NEER, formed NextEra Energy Partners, LP (NEP) 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). On July 1, 2014, NEP closed its initial public offering (IPO) by issuing 18,687,500 common units representing limited partner interests. The proceeds from the sale of the common units, net of underwriting discounts, commissions and structuring fees, were approximately $ 438 million . NEP used such proceeds to purchase 18,687,500 common units of NEP OpCo, of which approximately $ 288 million was used to purchase common units from an indirect wholly owned subsidiary of NEE and $ 150 million was used to purchase common units from NEP OpCo. Through an indirect wholly owned subsidiary, NEE retained 74,440,000 units of NEP OpCo representing a 79.9% interest in NEP's operating projects. Additionally, NEE owns a controlling general partner interest in NEP and consolidates NEP for financial reporting purposes and presents NEP's limited partner interest as a noncontrolling interest in NEE's consolidated financial statements. Certain equity and asset transactions between NEP, NEER and NEP OpCo involve the exchange of cash, energy projects and ownership interests in NEP OpCo. These exchanges are accounted for under the profit sharing method and resulted in a profit sharing liability, net of amortization, of approximately $ 757 million and $ 447 million at December 31, 2016 and 2015 , respectively, which is reflected in noncurrent other liabilities on NEE's consolidated balance sheets. The profit sharing liability will be amortized into income on a straight-line basis over the estimated useful lives of the underlying energy projects held by NEP OpCo. Accordingly, the profit sharing liability amortization totaled approximately $ 37 million during 2016 and is included in taxes other than income taxes and other - net in NEE’s consolidated statements of income. During the purchase price adjustment period associated with the IPO, which ended in November 2016, approximately $288 million of the profit sharing liability was not amortized. During 2015 and 2016, NEP sold an additional 35,527,435 common units and purchased an additional 35,527,435 NEP OpCo common units. Also, in 2015, a subsidiary of NEE purchased 27,000,000 of NEP OpCo's common units. After giving effect to these transactions, NEE’s partnership interest in NEP OpCo's operating projects is approximately 65.2% as of December 31, 2016 . As of December 31, 2016 , NEP, through NEER's contribution of energy projects to NEP OpCo, owns or has an interest in a portfolio of 22 wind and solar projects with generating capacity totaling approximately 2,787 megawatts (MW), as well as a portfolio of seven long-term contracted natural gas pipeline assets located in Texas. In October 2015, NEE authorized a program to purchase, from time to time, up to $ 150 million of common units representing limited partner interests of NEP. Under the program, any purchases may be made in amounts, at prices and at such times as NEE or its subsidiaries deem appropriate, all subject to market conditions and other considerations. The common unit purchase program does not require NEE to acquire any specific number of common units and may be modified or terminated by NEE at any time. The purchases may be made in the open market or in privately negotiated transactions. As of December 31, 2016 , NEE had purchased approximately $ 36 million of NEP common units under this program.
Rate Regulation	Rate Regulation - FPL is subject to rate regulation by the Florida Public Service Commission (FPSC) and the Federal Energy Regulatory Commission (FERC). Its rates are designed to recover the cost of providing electric 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, 2016 2015 2016 2015 (millions) Regulatory assets: Current: Derivatives $ — $ 218 $ — $ 218 Storm reserve deficiency 203 — 203 — Other 321 285 321 284 Total $ 524 $ 503 $ 524 $ 502 Noncurrent: Purchased power agreement termination $ 636 $ 726 $ 636 $ 726 Other 1,258 1,052 937 787 Total $ 1,894 $ 1,778 $ 1,573 $ 1,513 Regulatory liabilities: Current: Derivatives $ 208 $ — $ 208 $ — Other 91 14 86 12 Total $ 299 $ 14 $ 294 $ 12 Noncurrent: Accrued asset removal costs $ 1,956 $ 1,930 $ 1,944 $ 1,921 Asset retirement obligation regulatory expense difference 2,294 2,182 2,294 2,182 Other 656 494 655 492 Total $ 4,906 $ 4,606 $ 4,893 $ 4,595 Cost recovery clauses, which are designed to permit full recovery of certain costs and provide a return on certain assets allowed to be recovered through various clauses, include substantially all fuel, purchased power and interchange expense, certain costs associated with the acquisition of certain generation facilities, certain construction-related costs for certain of FPL's solar generation facilities, and conservation and certain environmental-related costs. Revenues from cost recovery clauses are recorded when billed; FPL achieves matching of costs and related revenues by deferring the net underrecovery or overrecovery. Any underrecovered costs or overrecovered revenues are collected from or returned to customers in subsequent periods. In 2015, FPL assumed ownership of a 250 MW coal-fired generation facility located in Jacksonville, Florida (Cedar Bay generation facility) and terminated its long-term purchased power agreement for substantially all of the facility’s capacity and energy for a purchase price of approximately $521 million . The FPSC approved a stipulation and settlement between the State of Florida Office of Public Counsel and FPL regarding issues relating to the ratemaking treatment for the Cedar Bay generation facility which provides for recovery of the purchase price and associated income tax gross-up as a regulatory asset of approximately $847 million which will be amortized over approximately nine years . At December 31, 2016 and 2015 , the regulatory assets, net of amortization, totaled approximately $726 million and $817 million , respectively, and are included in current and noncurrent regulatory assets on NEE’s and FPL’s consolidated balance sheets. This settlement also reduced the reserve amount that was available for amortization under the 2012 rate agreement by $30 million to $370 million . See Revenues and Rates - FPL Rates Effective January 2013 through December 2016 below. In December 2016, FPL retired the Cedar Bay generation facility. 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.
Revenues and Rates	Revenues and Rates - FPL's retail and wholesale utility rate schedules are approved by the FPSC and the FERC, respectively. FPL records unbilled base revenues for the estimated amount of energy delivered to customers but not yet billed. FPL's unbilled base revenues are included in customer receivables on NEE's and FPL's consolidated balance sheets and amounted to approximately $261 million and $246 million at December 31, 2016 and 2015 , respectively. FPL's operating revenues also include amounts resulting from cost recovery clauses (see Rate Regulation above), franchise fees, gross receipts taxes and surcharges related to storm-recovery bonds (see Note 8 - FPL). Franchise fees and gross receipts taxes are imposed on FPL; however, the FPSC allows FPL to include in the amounts charged to customers the amount of the gross receipts tax for all customers and the franchise fee for those customers located in the jurisdiction that imposes the amount. Accordingly, franchise fees and gross receipts taxes are reported gross in operating revenues and taxes other than income taxes and other in NEE's and FPL's consolidated statements of income and were approximately $700 million , $722 million and $716 million in 2016, 2015 and 2014 , respectively. The revenues from the surcharges related to storm-recovery bonds included in operating revenues in NEE's and FPL's consolidated statements of income were approximately $119 million , $115 million and $109 million in 2016, 2015 and 2014 , 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.
Revenue Recognition	NEER's revenue is recorded on the basis of commodities delivered, contracts settled or services rendered and includes estimated amounts yet to be billed to customers. Certain 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. In May 2014, the Financial Accounting Standards Board (FASB) issued an accounting standards update which provides guidance on the recognition of revenue from contracts with customers and requires additional disclosures about the nature, amount, timing and uncertainty of revenue and cash flows from an entity's contracts with customers. The standards update will be effective for NEE and FPL beginning January 1, 2018 with early adoption on January 1, 2017 permitted. The standards update may be applied retrospectively to each prior period presented or retrospectively with the cumulative effect recognized as an adjustment to retained earnings as of the date of initial application (modified retrospective method). NEE and FPL are currently reviewing individual contracts within various identified revenue streams in order to determine the impact, if any, this standards update will have on their consolidated financial statements. A number of industry-specific implementation issues are still unresolved and the final resolution of certain of these issues could impact NEE's and/or FPL's current accounting policies and/or revenue recognition patterns. NEE and FPL currently anticipate adopting the standards update on January 1, 2018 using the modified retrospective method.
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. 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. At December 31, 2016 , the electric generation, transmission, distribution and general facilities of FPL represented approximately 50% , 11% , 33% and 6% , respectively, of FPL's gross investment in electric utility plant in service and other property. Substantially all of FPL's properties are subject to the lien of FPL's mortgage, which secures most debt securities issued by FPL. A number of NEER's generation and pipeline facilities are encumbered by liens securing various financings. The net book value of NEER's assets serving as collateral was approximately $15.5 billion at December 31, 2016 . The American Recovery and Reinvestment Act of 2009, as amended (Recovery Act), provided for an option to elect a cash grant (convertible investment tax credits (ITCs)) for certain renewable energy property (renewable property). Convertible ITCs are recorded as a reduction in property, plant and equipment on NEE's and FPL's consolidated balance sheets and are amortized as a reduction to depreciation and amortization expense over the estimated life of the related property. At December 31, 2016 and 2015 , convertible ITCs, net of amortization, were approximately $2.1 billion ( $147 million at FPL) and $1.8 billion ( $153 million at FPL). At December 31, 2016 and 2015 , approximately $289 million and $207 million , respectively, of such convertible ITCs are included primarily in other receivables on NEE's consolidated balance sheets. Depreciation of FPL's electric property is primarily provided on a straight-line average remaining life basis. FPL includes in depreciation expense a provision for fossil and solar plant dismantlement, interim asset removal costs, accretion related to asset retirement obligations (see Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below), storm recovery amortization and amortization of pre-construction costs associated with planned nuclear units recovered through a cost recovery clause. For substantially all of FPL's property, depreciation studies are typically performed and filed with the FPSC every four years. In accordance with the 2012 rate agreement, FPL was not required to file depreciation studies during the effective period of the agreement; therefore, previously approved depreciation rates which became effective January 1, 2010 remained in effect through December 2016. As discussed in Revenues and Rates above, the use of reserve amortization was permitted under the 2012 rate agreement. In accordance with the 2012 rate agreement, FPL recorded reserve amortization (reversal) of approximately $13 million , $(15) million and $(33) million in 2016, 2015 and 2014 , respectively. The reserve is amortized as a reduction of (or reversed as an increase to) accrued asset removal costs which is reflected in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. The weighted annual composite depreciation and amortization rate for FPL's electric utility plant in service, including capitalized software, but excluding the effects of decommissioning, dismantlement and the depreciation adjustments discussed above, was approximately 3.4% , 3.3% and 3.3% for 2016, 2015 and 2014 , respectively. As part of the 2016 rate agreement, the FPSC approved new depreciation rates which became effective January 1, 2017. These new rates are expected to increase depreciation expense. The 2016 rate agreement also permits reserve amortization during the term of the agreement. See Revenues and Rates above. FPL files a twelve-month forecast with the FPSC each year which contains a regulatory ROE intended to be earned based on the best information FPL has at that time assuming normal weather. This forecast establishes a fixed targeted regulatory ROE. In order to earn the targeted regulatory ROE in each reporting period under the 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. NEER's electric plant in service less salvage value, if any, are depreciated primarily using the straight-line method over their estimated useful lives. At December 31, 2016 and 2015 , wind, nuclear, natural gas and solar plants represented approximately 62% and 62% , 10% and 11% , less than 1% and 3% , and 14% and 9% , respectively, of NEER's depreciable electric plant in service and other property. The estimated useful lives of NEER's plants range primarily from 25 to 30 years for wind, natural gas and solar plants and from 25 to 47 years for nuclear plants. NEER reviews the estimated useful lives of its fixed assets on an ongoing basis. NEER's oil and gas production assets, representing approximately 8% and 7% , respectively, of NEER's depreciable electric plant in service and other property at December 31, 2016 and 2015 , 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 13 - 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 non-cash item which represents the allowed cost of capital, including an ROE, used to finance construction projects. The portion of AFUDC attributable to borrowed funds is recorded as a reduction of interest expense and the remainder is recorded as other income. For FPL, FPSC rules limit the recording of AFUDC to projects that have an estimated cost in excess of 0.5% of a utility's plant in service balance and require more than one year to complete. FPSC rules allow construction projects below the 0.5% threshold as a component of rate base. During each of 2016, 2015 and 2014 , FPL capitalized AFUDC at a rate of 6.34% , which amounted to approximately $97 million , $88 million and $50 million , respectively. See Note 13 - Commitments. 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 a power plant or sale of development rights. At December 31, 2016 and 2015 , NEER's capitalized development costs totaled approximately $193 million and $133 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 no longer probable that these costs will 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 capitalized on construction projects amounted to approximately $107 million , $100 million and $104 million during 2016, 2015 and 2014 , respectively. Interest expense allocated from NextEra Energy Capital Holdings, Inc. (NEECH) to NEER is based on a deemed capital structure of 70% debt. Upon commencement of plant operation, costs associated with construction work in progress are transferred to electric plant in service and other property.
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. The asset retirement cost is subsequently allocated to expense, for NEE's non-rate regulated operations, and regulatory liability, for FPL, 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 the consolidated statements of income for NEE's non-rate regulated operations, and ARO and regulatory liability, in the case of FPL. 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, in the case of NEE's non-rate regulated operations, and ARO and regulatory liability, in the case of FPL. See Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below and Note 12.
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs	Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs - For ratemaking purposes, FPL accrues for the cost of end of life retirement and disposal of its nuclear, fossil and solar plants over the expected service life of each unit based on nuclear decommissioning and fossil and solar dismantlement studies periodically filed with the FPSC. In addition, FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC. As approved by the FPSC, FPL previously suspended its annual decommissioning accrual. For financial reporting purposes, FPL recognizes decommissioning and dismantlement liabilities in accordance with accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred. Any differences between expense recognized for financial reporting purposes and the amount recovered through rates are reported as a regulatory liability in accordance with regulatory accounting. See Revenues and Rates, Electric Plant, Depreciation and Amortization, Asset Retirement Obligations above and Note 12. Nuclear decommissioning studies are performed at least every five years and are submitted to the FPSC for approval. FPL filed updated nuclear decommissioning studies with the FPSC in December 2015. These studies reflect FPL's current plans, under the operating licenses, for prompt dismantlement of Turkey Point Units Nos. 3 and 4 following the end of plant operation with decommissioning activities commencing in 2032 and 2033, respectively, and provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the prompt 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. The studies indicate 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, to be approximately $7.5 billion , or $3.0 billion expressed in 2016 dollars. Restricted funds for the payment of future expenditures to decommission FPL's nuclear units are included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's and FPL's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily classified as available for sale and 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 offset in the related regulatory liability accounts. FPL does not currently make contributions to the decommissioning funds, other than the reinvestment of fund earnings. During 2016 , 2015 and 2014 fund earnings on decommissioning funds were approximately $102 million , $96 million and $91 million , respectively. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. Fossil and solar plant dismantlement studies are typically performed at least every four years and are submitted to the FPSC for approval. In accordance with the 2012 rate agreement, FPL was not required to file fossil and solar dismantlement studies during the effective period of the agreement; therefore, previously approved studies which became effective January 1, 2010 remained in effect through December 2016 and resulted in an annual expense of $18 million which is recorded in depreciation and amortization expense in NEE's and FPL's consolidated statements of income. As part of the 2016 rate agreement, the FPSC approved a new annual expense of $26 million based on FPL's 2016 fossil and solar dismantlement studies which became effective January 1, 2017. At December 31, 2016 , FPL's portion of the ultimate cost to dismantle its fossil and solar units is approximately $1.3 billion , or $480 million expressed in 2016 dollars. NEER records 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, when required in accordance with accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred. The liabilities are being accreted using the interest method through the date decommissioning or dismantlement activities are expected to be complete. See Note 12. At December 31, 2016 and 2015 , NEER's ARO, which is primarily related to nuclear decommissioning and wind and solar dismantlement, was approximately $817 million and $647 million , respectively, and was primarily determined using various internal and external data and applying a probability percentage to a variety of scenarios regarding the life of the plant and timing of decommissioning or dismantlement. NEER's portion of the ultimate cost of decommissioning its nuclear plants, including costs associated with spent fuel storage above what is expected to be refunded by the DOE under a spent fuel settlement agreement, is estimated to be approximately $11.8 billion , or $2.0 billion expressed in 2016 dollars. The ultimate cost to dismantle NEER's wind and solar facilities is estimated to be approximately $1.8 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 2015. Seabrook's decommissioning funding plan is also subject to annual review by the NDFC. Currently, there are no ongoing decommissioning funding requirements for Seabrook, Duane Arnold and Point Beach, however, the U.S. Nuclear Regulatory Commission (NRC), and in the case of Seabrook, the NDFC, has the authority to require additional funding in the future. NEER's portion of Seabrook's, Duane Arnold's and Point Beach's restricted funds for the payment of future expenditures to decommission these plants is included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily classified as available for sale and carried at fair value. Market adjustments result in a corresponding adjustment to other comprehensive income (OCI), except for unrealized losses associated with marketable securities considered to be other than temporary, including any credit losses, which are recognized as other than temporary impairment losses on securities held in nuclear decommissioning funds in NEE's consolidated statements of income. Fund earnings are recognized in income and are reinvested in the funds. See Note 4. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes.
Major Maintenance Costs	Major Maintenance Costs - FPL recognizes costs associated with planned major nuclear maintenance in accordance with regulatory treatment and records the related accrual as a regulatory liability. FPL expenses costs associated with planned fossil maintenance as incurred. FPL's estimated nuclear maintenance costs for each nuclear unit's next planned outage are accrued over the period from the end of the last outage to the end of the next planned outage. Any difference between the estimated and actual costs is included in O&M expenses when known. The accrued liability for nuclear maintenance costs at December 31, 2016 and 2015 totaled approximately $65 million and $48 million , respectively, and is included in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. For the years ended December 31, 2016, 2015 and 2014 , FPL recognized approximately $89 million , $90 million and $76 million , respectively, in nuclear maintenance costs which are primarily included in O&M expenses in NEE's and FPL's consolidated statements of income. 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 and amortized on a unit of production method over the period from the end of the last outage to the beginning of the next planned outage. NEER's capitalized major maintenance costs, net of accumulated amortization, totaled approximately $69 million and $97 million at December 31, 2016 and 2015 , respectively, and are included in noncurrent other assets on NEE's consolidated balance sheets. For the years ended December 31, 2016, 2015 and 2014 , NEER amortized approximately $74 million , $79 million and $81 million in major maintenance costs which are included in O&M expenses in NEE's consolidated statements of income.
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, 2016 and 2015 , NEE had approximately $311 million ( $120 million for FPL) and $244 million ($ 75 million for FPL), respectively, of restricted cash included in other current assets on NEE's and FPL's consolidated balance sheets, which was primarily related to margin cash collateral requirements, debt service payments and bond proceeds held for construction at FPL. Where offsetting positions exist, restricted cash related to margin cash collateral is netted against derivative instruments. See Note 3.
Allowance for Doubtful Accounts	Allowance for Doubtful Accounts - FPL maintains an accumulated provision for uncollectible customer accounts receivable that is estimated using a percentage, derived from historical revenue and write-off trends, of the previous five months of revenue. Additional amounts are included in the provision to address specific items that are not considered in the calculation described above. 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 and, when necessary, using the specific identification method for all other receivables.
Inventory	Inventory - FPL values materials, supplies and fossil fuel inventory using a weighted-average cost method. NEER's materials, supplies and fossil fuel inventories are carried at the lower of weighted-average cost or market, unless evidence indicates that the weighted-average cost (even if in excess of market) 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 gas 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.
Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve	Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve - In connection with the 2007 storm-recovery bond financing (see Note 8 - FPL), the net proceeds to FPL from the sale of the storm-recovery property were used primarily to reimburse FPL for its estimated net of tax deficiency in its storm and property insurance reserve (storm reserve) and provide for a storm and property insurance reserve fund (storm fund). Upon the issuance of the storm-recovery bonds, the storm reserve deficiency was reclassified to securitized storm-recovery costs which is recorded as a current and noncurrent regulatory asset on NEE's and FPL's consolidated balance sheets. As storm-recovery charges are billed to customers (which are included in operating revenues), the securitized storm-recovery costs are amortized and included in depreciation and amortization expense in NEE's and FPL's consolidated statements of income. Marketable securities held in the storm fund are classified as available for sale and 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 fund. 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 fund is included in special use funds on NEE's and FPL's consolidated balance sheets and was approximately $74 million at December 31, 2015 . During the fourth quarter of 2016, all available funds were withdrawn from the storm fund to pay for the storm restoration costs associated with Hurricane Hermine and Hurricane Matthew (see below regarding Hurricane Hermine and Hurricane Matthew). FPL was impacted by Hurricane Hermine in September 2016 and Hurricane Matthew in October 2016. Hurricane Matthew resulted in damage in much of FPL's service territory and caused approximately 1.2 million of FPL's customers to lose electrical service. Damage to FPL property was primarily limited to the transmission and distribution systems. Storm restoration costs eligible for recovery for both events totaled approximately $315 million , the majority of which relates to Hurricane Matthew. Prior to these storms, FPL's storm and property insurance reserve had the capacity to absorb approximately $112 million in additional storm restoration costs ( $20 million of which was absorbed by Hurricane Hermine). At December 31, 2016, FPL's storm and property insurance reserve was fully depleted and storm restoration costs expected to be recoverable from customers exceeded the balance of the storm reserve by approximately $203 million . This deficiency has been deferred and recorded as a regulatory asset on NEE's and FPL's consolidated balance sheets. In February 2017, the FPSC approved FPL’s request to begin recovering eligible storm restoration costs over the reserve amount, plus approximately $117 million to replenish the reserve to the level authorized by the 2012 rate agreement. The recovery will take place through an interim surcharge that applies for a 12-month period starting March 1, 2017, with the amount collected subject to refund based on an FPSC prudence review. The replenished reserve will not initially be reflected on NEE’s and FPL’s consolidated balance sheets because the associated regulatory asset does not meet the specific recognition criteria under the accounting guidance for certain regulated entities. As a result, as the storm surcharge is billed to customers (which is recorded as operating revenues), the storm reserve will be recognized as a regulatory liability and charged to depreciation and amortization expense in NEE’s and FPL’s consolidated statements of income.
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. An impairment loss is required to be recognized if the carrying value of the asset exceeds the undiscounted future net cash flows associated with that asset. The impairment loss to be recognized is the amount by which the carrying value of the long-lived asset exceeds the asset's fair value. In most instances, the fair value is determined by discounting estimated future cash flows using an appropriate interest rate.
Goodwill and Other Intangible Assets	NEE's goodwill relates to various acquisitions which were accounted for using the purchase method of accounting. Other intangible assets subject to amortization are amortized, primarily on a straight-line basis, over their estimated useful lives. Amortization expense was approximately $35 million , $17 million and $15 million for the years ended December 31, 2016, 2015 and 2014 , respectively, and is expected to be approximately $ 31 million , $46 million , $39 million , $26 million and $19 million for 2017, 2018, 2019, 2020 and 2021, respectively. Goodwill and other intangible assets are primarily included in noncurrent other assets on NEE's consolidated balance sheets. 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 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. See Note 10 - Stock-Based Compensation.
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 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 asset totaled $ 289 million ( $266 million for FPL) and $ 283 million ( $268 million for FPL) at December 31, 2016 and 2015 , respectively, and is being amortized in accordance with the regulatory treatment over the estimated lives of the assets or liabilities for which the deferred tax amount was initially recognized. Production tax credits (PTCs) are recognized as wind energy is generated and sold based on a per kWh rate prescribed in applicable federal and state statutes and are recorded as a reduction of current income taxes payable, unless limited by tax law in which instance they are recorded as deferred tax assets. NEER recognizes ITCs as a reduction to income tax expense when the related energy property is placed into service. FPL recognizes ITCs as a reduction to income tax expense over the depreciable life of the related energy property. At December 31, 2016 and 2015 , FPL’s accumulated deferred ITCs were approximately $ 123 million and $ 3 million , respectively, and are included in noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. NEE and FPL record a deferred income tax benefit created by the convertible ITCs on the difference between the financial statement and tax bases of renewable property. For NEER, this deferred income tax benefit is recorded in income tax expense in the year that the renewable property is placed in service. For FPL, this deferred income tax benefit is offset by a regulatory liability, which is amortized as a reduction of depreciation expense over the approximate lives of the related renewable property in accordance with the regulatory treatment. At December 31, 2016 and 2015 , the net deferred income tax benefits associated with FPL's convertible ITCs were approximately $ 46 million and $ 48 million , respectively, and are included in noncurrent regulatory assets and noncurrent regulatory liabilities on NEE's and FPL's consolidated balance sheets. A valuation allowance is recorded to reduce the carrying amounts of deferred tax assets when it is more likely than not that such assets will not be realized. NEE recognizes interest income (expense) related to unrecognized tax benefits (liabilities) in interest income and interest expense, respectively, net of the amount deferred at FPL. At FPL, the offset to accrued interest receivable (payable) on income taxes is classified as a regulatory liability (regulatory asset) which will be amortized to income (expense) over a five-year period upon settlement in accordance with regulatory treatment. All tax positions taken by NEE in its income tax returns that are recognized in the financial statements must satisfy a more-likely-than-not threshold. NEE and its subsidiaries file income tax returns in the U.S. federal jurisdiction and various states, the most significant of which is Florida, and certain foreign jurisdictions. Federal tax liabilities, with the exception of certain refund claims, are effectively settled for all years prior to 2013. State and foreign tax liabilities, which have varied statutes of limitations regarding additional assessments, are generally effectively settled for years prior to 2009. At December 31, 2016 , NEE had unrecognized tax benefits of approximately $ 40 million that, if disallowed, 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	Sale of Differential Membership Interests - Certain subsidiaries of NEER sold their Class B membership interest in entities that have ownership interests in wind and solar facilities, with generating capacity totaling approximately 6,847 MW and 374 MW, respectively, at December 31, 2016 , to third-party investors. In exchange for the cash received, the holders of the Class B membership interests will receive a portion of the economic attributes of the facilities, including income tax attributes, for variable periods. The transactions are not treated as a sale under the accounting rules and the proceeds received are deferred and recorded as a liability in deferral related to differential membership interests - VIEs on NEE's consolidated balance sheets. The deferred amount is being recognized in benefits associated with differential membership interests - net in NEE's consolidated statements of income as the Class B members receive their portion of the economic attributes. NEE continues to operate and manage the wind and solar facilities, and consolidates the entities that own the wind and solar facilities.
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 8.
New Accounting Pronouncements	Leases - In February 2016, the FASB issued an accounting standards update which requires, among other things, that lessees recognize a lease liability, initially measured at the present value of the future lease payments; and a right-of-use asset for all leases (with the exception of short-term leases). The standards update will be effective for NEE and FPL beginning January 1, 2019. Early adoption is permitted. Lessees and lessors must apply a modified retrospective approach for all leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. NEE and FPL are currently reviewing their portfolio of contracts and are in the process of determining the proper application of the standards update to these contracts in order to determine the impact the adoption will have on their consolidated financial statements, including timing of adoption. Financial Instruments Accounting Standards Update - In January 2016, the FASB issued an accounting standards update which modifies current guidance for financial instruments. The standards update requires that equity investments (except investments accounted for under the equity method and investments that are consolidated) be measured at fair value with changes in fair value recognized in net income and provides an option for those equity investments that do not have readily determinable fair values to be measured at cost minus impairment (plus or minus changes resulting from observable price changes). The standards update also makes certain changes to presentation and disclosure requirements of financial instruments. The standards update is effective for NEE and FPL beginning January 1, 2018 and will be applied retrospectively with the cumulative effect recognized as of the date of initial application. NEE and FPL are currently evaluating the effect the adoption of this standards update will have, if any, on their consolidated financial statements.
Assets and Liabilities Associated with Assets Held for Sale	Assets and Liabilities Associated with Assets Held for Sale - In April 2016, a subsidiary of NEER completed the sale of its ownership interest in merchant natural gas generation facilities located in Texas with a total generating capacity of 2,884 MW for net cash proceeds of approximately $456 million , after transaction costs and working capital adjustments. A NEER affiliate continued to operate the facilities included in the sale through September 2016. In connection with the sale and the related consolidating state income tax effects, a gain of approximately $254 million ( $106 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2016 and is included in losses (gains) on disposal of assets - net. The carrying amounts of the major classes of assets and liabilities related to the facilities that were classified as held for sale on NEE's consolidated balance sheets as of December 31, 2015 primarily represent property, plant and equipment and the related long-term debt. In 2016, a subsidiary of NEER initiated a plan, received internal authorization and completed the sale of its ownership interest in natural gas generation facilities located primarily in Pennsylvania with a total generating capacity of 840 MW for net cash proceeds of approximately $260 million , after transaction costs and working capital adjustments. In connection with the sale and the related consolidating state income tax effects, a gain of approximately $191 million ($ 113 million after tax) was recorded in NEE's consolidated statements of income for the year ended December 31, 2016 and is included in losses (gains) on disposal of assets - net. In January 2017, an indirect wholly owned subsidiary of NEE completed the sale of its membership interests in its fiber-optic telecommunications business (FPL FiberNet) for net cash proceeds of approximately $1.1 billion , after repayment of $370 million of related long-term debt. In connection with the sale and the related consolidating state income tax effects, a gain of approximately $1.1 billion (approximately $700 million after tax) will be recorded in NEE's consolidated statements of income during the three-months ended March 31, 2017. The carrying amounts of the major classes of assets and liabilities related to FPL FiberNet that were classified as held for sale on NEE's consolidated balance sheets as of December 31, 2016 primarily represent property, plant and equipment and the related long-term debt.
Terminated Merger	Merger Termination - In 2014, NEE and Hawaiian Electric Industries, Inc. (HEI) entered into an Agreement and Plan of Merger (the HEI merger agreement) pursuant to which Hawaiian Electric Company, Inc. (HECO), HEI's wholly owned electric utility subsidiary, was to become a wholly owned subsidiary of NEE. In July 2016, the Hawaii Public Utilities Commission issued an order dismissing NEE's and HECO's merger application and, as a result, NEE terminated the HEI merger agreement. Pursuant to the terms of the HEI merger agreement, NEE paid HEI a termination fee of $90 million plus reimbursement to HEI for out-of-pocket expenses incurred in connection with the HEI merger agreement of $5 million , which is included in merger-related expenses in NEE's consolidated statements of income for the year ended December 31, 2016.
Fair Value of Financial Instruments, Policy	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. Cash Equivalents and Restricted Cash - NEE primarily holds investments in money market funds. The fair value of these funds is estimated using a market approach based on current observable market prices. Special Use Funds and Other Investments - NEE and FPL hold primarily debt and equity securities directly, as well as indirectly through commingled funds. Substantially all directly held equity securities are valued at their quoted market prices. For directly held debt securities, multiple prices and price types are obtained from pricing vendors whenever possible, which enables cross-provider validations. A primary price source is identified based on asset type, class or issue of each security. Commingled funds, which are similar to mutual funds, are maintained by banks or investment companies and hold certain investments in accordance with a stated set of objectives. The fair value of commingled funds is primarily derived from the quoted prices in active markets of the underlying securities. Because the fund shares are offered to a limited group of investors, they are not considered to be traded in an active market. Derivative Instruments - 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.
Derivatives, Policy	NEE and FPL use derivative instruments (primarily swaps, options, futures and forwards) to manage the commodity price risk 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. 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 gas marketing and trading activities to take advantage of expected future favorable price movements and changes in the expected volatility of prices in the energy markets. These risk management activities involve the use of derivative instruments executed within prescribed limits to manage the risk associated with fluctuating commodity prices. Transactions in derivative instruments are executed on recognized exchanges or via the over-the-counter (OTC) markets, depending on the most favorable credit terms and market execution factors. For NEER's power generation and gas infrastructure assets, derivative instruments are used to hedge all or a portion of the expected output of these assets. These hedges are designed to reduce the effect of adverse changes in the wholesale forward commodity markets associated with NEER's power generation and gas infrastructure assets. With regard to full energy and capacity requirements services, NEER is required to vary the quantity of energy and related services based on the load demands of the customers served. For this type of transaction, derivative instruments are used to hedge the anticipated electricity quantities required to serve these customers and reduce the effect of unfavorable changes in the forward energy markets. Additionally, NEER takes positions in energy markets based on differences between actual forward market levels and management's view of fundamental market conditions, including supply/demand imbalances, changes in traditional flows of energy, changes in short- and long-term weather patterns and anticipated regulatory and legislative outcomes. NEER uses derivative instruments to realize value from these market dislocations, subject to strict risk management limits around market, operational and credit exposure. Derivative instruments, when required to be marked to market, are recorded on NEE's and FPL's consolidated balance sheets as either an asset or liability measured at fair value. At FPL, substantially all changes in the derivatives' fair value are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the fuel and purchased power cost recovery clause (fuel clause). For NEE's non-rate regulated operations, predominantly NEER, essentially all changes in the derivatives' fair value for power purchases and sales, fuel sales and trading activities are recognized on a net basis in operating revenues; fuel purchases used in the production of electricity are recognized in fuel, purchased power and interchange expense; and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's consolidated statements of income. Settlement gains and losses are included within the line items in the consolidated statements of income to which they relate. Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the consolidated statements of income. For commodity derivatives, NEE believes that, where offsetting positions exist at the same location for the same time, the transactions are considered to have been netted and therefore physical delivery has been deemed not to have occurred for financial reporting purposes. Settlements related to derivative instruments are primarily recognized in net cash provided by operating activities in NEE's and FPL's consolidated statements of cash flows. In January 2016, NEE discontinued hedge accounting for its cash flow and fair value hedges related to interest rate and foreign currency derivative instruments and, therefore, all changes in the derivatives' fair value, as well as the transaction gain or loss on foreign denominated debt, are recognized in interest expense in NEE's consolidated statements of income
Earnings Per Share	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.

Summary of Significant Accoun27

Summary of Significant Accounting and Reporting Policies (Tables)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Schedule of Regulatory Assets and Liabilities [Table Text Block]	NEE's and FPL's regulatory assets and liabilities are as follows: NEE FPL December 31, December 31, 2016 2015 2016 2015 (millions) Regulatory assets: Current: Derivatives $ — $ 218 $ — $ 218 Storm reserve deficiency 203 — 203 — Other 321 285 321 284 Total $ 524 $ 503 $ 524 $ 502 Noncurrent: Purchased power agreement termination $ 636 $ 726 $ 636 $ 726 Other 1,258 1,052 937 787 Total $ 1,894 $ 1,778 $ 1,573 $ 1,513 Regulatory liabilities: Current: Derivatives $ 208 $ — $ 208 $ — Other 91 14 86 12 Total $ 299 $ 14 $ 294 $ 12 Noncurrent: Accrued asset removal costs $ 1,956 $ 1,930 $ 1,944 $ 1,921 Asset retirement obligation regulatory expense difference 2,294 2,182 2,294 2,182 Other 656 494 655 492 Total $ 4,906 $ 4,606 $ 4,893 $ 4,595
Schedule of Goodwill and Other Intangible Assets	Goodwill and Other Intangible Assets - NEE's goodwill and other intangible assets are as follows: Weighted- Average Useful Lives December 31, 2016 2015 (years) (millions) Goodwill (by reporting unit): NEER segment: Gas infrastructure, primarily Texas pipelines $ 641 $ 635 Customer supply 72 72 Generation assets 38 43 Other 28 28 Total goodwill $ 779 $ 778 Other intangible assets not subject to amortization, primarily land easements $ 143 $ 143 Other intangible assets subject to amortization: Customer relationships associated with gas infrastructure 41 $ 700 $ 720 Purchased power agreements 22 444 328 Other, primarily transmission and development rights and customer lists 19 81 136 Total 1,225 1,184 Accumulated amortization (115 ) (120 ) Total other intangible assets subject to amortization - net $ 1,110 $ 1,064

Employee Retirement Benefits (T

Employee Retirement Benefits (Tables)	12 Months Ended
	Dec. 31, 2016
Compensation and Retirement Disclosure [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: 2016 2015 (millions) Change in pension plan assets: Fair value of plan assets at January 1 $ 3,563 $ 3,698 Actual return on plan assets 217 (8 ) Benefit payments (129 ) (127 ) Fair value of plan assets at December 31 $ 3,651 $ 3,563 Change in pension benefit obligation: Obligation at January 1 $ 2,408 $ 2,454 Service cost 62 70 Interest cost 105 97 Plan amendments (19 ) — Actuarial losses (gains) - net 47 (86 ) Benefit payments (129 ) (127 ) Obligation at December 31 (a) $ 2,474 $ 2,408 Funded status: Prepaid pension benefit costs at NEE at December 31 $ 1,177 $ 1,155 Prepaid pension benefit costs at FPL at December 31 $ 1,301 $ 1,243 _________________________ (a) NEE's accumulated pension benefit obligation, which includes no assumption about future salary levels, at December 31, 2016 and 2015 was approximately $ 2,439 million and $ 2,366 million , respectively.
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: 2016 2015 (millions) Unrecognized prior service benefit (cost) (net of $2 tax expense and $1 tax benefit, respectively) $ 3 $ (2 ) Unrecognized losses (net of $55 and $38 tax benefit, respectively) (87 ) (60 ) Total $ (84 ) $ (62 )
Unrecognized amounts included in regulatory assets (liabilities)	NEE's unrecognized amounts included in regulatory assets yet to be recognized as components of net prepaid pension benefit costs are as follows: 2016 2015 (millions) Unrecognized prior service cost (benefit) $ (4 ) $ 9 Unrecognized losses 280 232 Total $ 276 $ 241
Significant assumptions used to determine benefit obligations and net periodic benefit (income) cost	The assumptions used to determine net periodic income for the pension plan are as follows: 2016 2015 2014 Discount rate 4.35 % 3.95 % 4.80 % Salary increase 4.10 % 4.10 % 4.00 % Expected long-term rate of return (a)(b) 7.35 % 7.35 % 7.75 % ______________________ (a) In developing the expected long-term rate of return on assets assumption for its pension plan, NEE evaluated input, including other qualitative and quantitative factors, from its actuaries and consultants, as well as information available in the marketplace. NEE considered different models, capital market return assumptions and historical returns for a portfolio with an equity/bond asset mix similar to its pension fund. NEE also considered its pension fund's historical compounded returns. (b) In 2016 and 2015, an expected long-term rate of return of 7.75% is presented net of investment management fees. The following table provides the assumptions used to determine the benefit obligation for the pension plan. These rates are used in determining net periodic income in the following year. 2016 2015 Discount rate (a) 4.09 % 4.35 % Salary increase 4.10 % 4.10 % _________________________ (a) Beginning in 2017, NEE changed its method of estimating the interest cost component of net periodic benefit costs and will use a full yield curve approach by applying a specific spot rate along the yield curve rather than a single weighted-average discount rate. Such change is not expected to have a material impact on the pension and postretirement plans' net periodic benefit costs.
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, 2016 (a) Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total (millions) Equity securities (b) $ 879 $ 16 $ 3 $ 898 Equity commingled vehicles (c) — 845 — 845 U.S. Government and municipal bonds 143 12 — 155 Corporate debt securities (d) 3 246 1 250 Asset-backed securities — 124 — 124 Debt security commingled vehicles — 22 — 22 Convertible securities (e) 21 277 — 298 Total investments in the fair value hierarchy $ 1,046 $ 1,542 $ 4 2,592 Total investments measured at net asset value (f) 1,059 Total fair value of plan assets $ 3,651 ______________________ (a) See Note 4 for discussion of fair value measurement techniques and inputs. (b) Includes foreign investments of $ 370 million . (c) Includes foreign investments of $ 261 million . (d) Includes foreign investments of $ 67 million . (e) Includes foreign investments of $ 31 million . (f) Includes foreign investments of $ 282 million . December 31, 2015 (a) Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total (millions) Equity securities (b) $ 910 $ 21 $ 1 $ 932 Equity commingled vehicles (c) — 792 — 792 U.S. Government and municipal bonds 110 13 — 123 Corporate debt securities (d) 2 277 1 280 Asset-backed securities — 167 — 167 Debt security commingled vehicles — 21 — 21 Convertible securities (e) 16 258 — 274 Total investments in the fair value hierarchy $ 1,038 $ 1,549 $ 2 2,589 Total investments measured at net asset value (f) 974 Total fair value of plan assets $ 3,563 ______________________ (a) See Note 4 for discussion of fair value measurement techniques and inputs. (b) Includes foreign investments of $ 384 million . (c) Includes foreign investments of $ 249 million . (d) Includes foreign investments of $ 68 million . (e) Includes foreign investments of $ 23 million . (f) Includes foreign investments of $ 283 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): 2017 $ 155 2018 $ 156 2019 $ 160 2020 $ 163 2021 $ 170 2022 - 2026 $ 879
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 2016 2015 2014 2016 2015 2014 (millions) Service cost $ 62 $ 70 $ 61 $ 2 $ 3 $ 3 Interest cost 105 97 101 13 13 16 Expected return on plan assets (260 ) (253 ) (241 ) (1 ) (1 ) (1 ) Amortization of prior service cost (benefit) 1 1 5 (2 ) (3 ) (3 ) Amortization of losses — — — — 2 — Net periodic (income) cost at NEE $ (92 ) $ (85 ) $ (74 ) $ 12 $ 14 $ 15 Net periodic (income) cost at FPL $ (58 ) $ (55 ) $ (47 ) $ 9 $ 11 $ 11
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: 2016 2015 2014 (millions) Prior service benefit (net of $3 and $3 tax expense, respectively) $ 4 $ — $ 4 Net losses (net of $16, $27 and $29 tax benefit, respectively) (26 ) (44 ) (45 ) Amortization of prior service benefit — — 1 Total $ (22 ) $ (44 ) $ (40 )
Components of net periodic benefit (income) cost recognized in regulatory assets (liabilities)	Regulatory Assets (Liabilities) - The components of net periodic (income) cost recognized during the year in regulatory assets (liabilities) for the pension plan are as follows: 2016 2015 (millions) Prior service benefit $ (12 ) $ — Unrecognized losses 48 104 Amortization of prior service benefit (1 ) (1 ) Total $ 35 $ 103

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2016
Derivative [Line Items]
Schedule of derivative instruments in statement of financial position, fair value	Fair Value of Derivative Instruments - The tables below present NEE's and FPL's gross derivative positions at December 31, 2016 and December 31, 2015 , 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 (see Note 4 - Recurring Fair Value Measurements for netting information), as well as the location of the net derivative position on the consolidated balance sheets. December 31, 2016 Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis Fair Values of Derivatives Not Assets Liabilities Assets Liabilities (millions) NEE: Commodity contracts $ 4,590 $ 2,968 $ 1,938 $ 483 Interest rate contracts 288 284 296 292 Foreign currency contracts 1 106 1 106 Total fair values $ 4,879 $ 3,358 $ 2,235 $ 881 FPL: Commodity contracts $ 212 $ 4 $ 209 $ 1 Net fair value by NEE balance sheet line item: Current derivative assets (a) $ 885 Noncurrent derivative assets (b) 1,350 Current derivative liabilities $ 404 Noncurrent derivative liabilities 477 Total derivatives $ 2,235 $ 881 Net fair value by FPL balance sheet line item: Current derivative assets $ 209 Current derivative liabilities $ 1 Total derivatives $ 209 $ 1 ______________________ (a) Reflects the netting of approximately $96 million in margin cash collateral received from counterparties. (b) Reflects the netting of approximately $71 million in margin cash collateral received from counterparties. December 31, 2015 Fair Values of Derivatives Designated as Hedging Instruments for Accounting Purposes - Gross Basis Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis Total Derivatives Combined - Net Basis Assets Liabilities Assets Liabilities Assets Liabilities (millions) NEE: Commodity contracts $ — $ — $ 5,906 $ 4,580 $ 1,937 $ 982 Interest rate contracts 33 155 2 160 34 319 Foreign currency contracts — 132 — — — 127 Total fair values $ 33 $ 287 $ 5,908 $ 4,740 $ 1,971 $ 1,428 FPL: Commodity contracts $ — $ — $ 7 $ 225 $ 4 $ 222 Net fair value by NEE balance sheet line item: Current derivative assets (a) $ 712 Assets held for sale 57 Noncurrent derivative assets (b) 1,202 Current derivative liabilities (c) $ 882 Liabilities associated with assets held for sale 16 Noncurrent derivative liabilities (d) 530 Total derivatives $ 1,971 $ 1,428 Net fair value by FPL balance sheet line item: Current derivative assets $ 3 Noncurrent other assets 1 Current derivative liabilities $ 222 Total derivatives $ 4 $ 222 ______________________ (a) Reflects the netting of approximately $279 million in margin cash collateral received from counterparties. (b) Reflects the netting of approximately $151 million in margin cash collateral received from counterparties. (c) Reflects the netting of approximately $46 million in margin cash collateral paid to counterparties. (d) Reflects the netting of approximately $13 million in margin cash collateral paid to counterparties.
Net notional volumes	NEE and FPL had derivative commodity contracts for the following net notional volumes: December 31, 2016 December 31, 2015 Commodity Type NEE FPL NEE FPL (millions) Power (84 ) MWh (a) — (112 ) MWh (a) — Natural gas 1,002 MMBtu (b) 618 MMBtu (b) 1,321 MMBtu (b) 833 MMBtu (b) Oil (7 ) barrels — (9 ) barrels — ______________________ (a) Megawatt-hours (b) One million British thermal units
Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative instruments, gain (loss) in statement of financial performance	Gains (losses) related to NEE's derivatives not designated as hedging instruments are recorded in NEE's consolidated statements of income as follows: Years Ended December 31, 2016 2015 2014 (millions) Commodity contracts: (a) Operating revenues $ 459 $ 932 $ 420 Fuel, purchased power and interchange (1 ) 8 1 Foreign currency contracts - interest expense 14 — — Foreign currency contracts - other - net (1 ) — (1 ) Interest rate contracts - interest expense 181 8 (64 ) Losses reclassified from AOCI to interest expense: Interest rate contracts (90 ) — — Foreign currency contracts (11 ) — — Total $ 551 $ 948 $ 356 ______________________ (a) For the years ended December 31, 2016 , 2015 and 2014 , FPL recorded gains (losses) of approximately $203 million , $(326) million and $(289) million , respectively, related to commodity contracts as regulatory liabilities (assets) on its consolidated balance sheets.
Cash Flow Hedging [Member]
Derivative [Line Items]
Derivative instruments, gain (loss) in statement of financial performance	Income Statement Impact of Derivative Instruments - Losses related to NEE's cash flow hedges, which were previously designated as hedging instruments, are recorded in NEE's consolidated financial statements (none at FPL) as follows: Year Ended Year Ended Interest Rate Contracts Foreign Currency Contracts Total Interest Rate Contracts Foreign Currency Contracts Total Losses recognized in OCI $ (113 ) $ (12 ) $ (125 ) $ (132 ) $ (89 ) $ (221 ) Losses reclassified from AOCI to net income $ (73 ) (a) $ (15 ) (b) $ (88 ) $ (77 ) (a) $ (78 ) (b) $ (155 ) ______________________ (a) Included in interest expense. (b) For 2015 and 2014, losses of approximately $11 million and $8 million , respectively, are included in interest expense and the balances are included in other - net.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Financial assets and liabilities and other fair value measurements	Recurring Fair Value Measurements - NEE's and FPL's financial assets and liabilities and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows: December 31, 2016 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: Cash equivalents and restricted cash: (b) NEE - equity securities $ 982 $ — $ — $ 982 FPL - equity securities $ 120 $ — $ — $ 120 Special use funds: (c) NEE: Equity securities $ 1,410 $ 1,503 (d) $ — $ 2,913 U.S. Government and municipal bonds $ 296 $ 170 $ — $ 466 Corporate debt securities $ 1 $ 763 $ — $ 764 Mortgage-backed securities $ — $ 498 $ — $ 498 Other debt securities $ — $ 81 $ — $ 81 FPL: Equity securities $ 373 $ 1,372 (d) $ — $ 1,745 U.S. Government and municipal bonds $ 221 $ 141 $ — $ 362 Corporate debt securities $ — $ 547 $ — $ 547 Mortgage-backed securities $ — $ 384 $ — $ 384 Other debt securities $ — $ 70 $ — $ 70 Other investments: NEE: Equity securities $ 26 $ 9 $ — $ 35 Debt securities $ 8 $ 153 $ — $ 161 Derivatives: NEE: Commodity contracts $ 1,563 $ 1,827 $ 1,200 $ (2,652 ) $ 1,938 (e) Interest rate contracts $ — $ 285 $ 3 $ 8 $ 296 (e) Foreign currency contracts $ — $ 1 $ — $ — $ 1 (e) FPL - commodity contracts $ — $ 208 $ 4 $ (3 ) $ 209 (e) Liabilities: Derivatives: NEE: Commodity contracts $ 1,476 $ 980 $ 512 $ (2,485 ) $ 483 (e) Interest rate contracts $ — $ 171 $ 113 $ 8 $ 292 (e) Foreign currency contracts $ — $ 106 $ — $ — $ 106 (e) FPL - commodity contracts $ — $ 1 $ 3 $ (3 ) $ 1 (e) ______________________ (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) Includes restricted cash of approximately $164 million ( $120 million for FPL) in other current assets on the consolidated balance sheets. (c) 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. (d) Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL. (e) See Note 3 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's consolidated balance sheets. December 31, 2015 Level 1 Level 2 Level 3 Netting (a) Total (millions) Assets: Cash equivalents and restricted cash: (b) NEE - equity securities $ 312 $ — $ — $ 312 FPL - equity securities $ 36 $ — $ — $ 36 Special use funds: (c) NEE: Equity securities $ 1,320 $ 1,354 (d) $ — $ 2,674 U.S. Government and municipal bonds $ 446 $ 166 $ — $ 612 Corporate debt securities $ — $ 713 $ — $ 713 Mortgage-backed securities $ — $ 412 $ — $ 412 Other debt securities $ — $ 52 $ — $ 52 FPL: Equity securities $ 364 $ 1,234 (d) $ — $ 1,598 U.S. Government and municipal bonds $ 335 $ 145 $ — $ 480 Corporate debt securities $ — $ 531 $ — $ 531 Mortgage-backed securities $ — $ 327 $ — $ 327 Other debt securities $ — $ 40 $ — $ 40 Other investments: NEE: Equity securities $ 30 $ 10 $ — $ 40 Debt securities $ 39 $ 132 $ — $ 171 Derivatives: NEE: Commodity contracts $ 2,187 $ 2,540 $ 1,179 $ (3,969 ) $ 1,937 (e) Interest rate contracts $ — $ 35 $ — $ (1 ) $ 34 (e) FPL - commodity contracts $ — $ 1 $ 6 $ (3 ) $ 4 (e) Liabilities: Derivatives: NEE: Commodity contracts $ 2,153 $ 1,887 $ 540 $ (3,598 ) $ 982 (e) Interest rate contracts $ — $ 214 $ 101 $ 4 $ 319 (e) Foreign currency contracts $ — $ 132 $ — $ (5 ) $ 127 (e) FPL - commodity contracts $ — $ 219 $ 6 $ (3 ) $ 222 (e) ______________________ (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) Includes restricted cash of approximately $61 million ( $36 million for FPL) in other current assets on the consolidated balance sheets. (c) 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. (d) Primarily invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL. (e) See Note 3 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's consolidated balance sheets.
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, 2016 2015 2014 NEE FPL NEE FPL NEE FPL (millions) Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year $ 538 $ — $ 622 $ 5 $ 622 $ — Realized and unrealized gains (losses): Included in earnings (a) 333 — 451 — (77 ) — Included in other comprehensive income 8 — 11 — 18 — Included in regulatory assets and liabilities 1 1 3 3 7 7 Purchases 261 — 180 — 55 — Settlements (390 ) — (473 ) (8 ) 194 (2 ) Issuances (195 ) — (202 ) — (122 ) — Transfers in (b) 19 — (13 ) — 80 — Transfers out (b) 3 — (41 ) — (155 ) — Fair value of net derivatives based on significant unobservable inputs at December 31 $ 578 $ 1 $ 538 $ — $ 622 $ 5 The amount of gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to derivatives still held at the reporting date (c) $ 219 $ — $ 277 $ — $ 248 $ — ______________________ (a) For the year ended December 31, 2016 , $397 million of realized and unrealized gains are reflected in the consolidated statements of income in operating revenues and the balance is reflected in interest expense. For the year ended December 31, 2015 , $462 million of realized and unrealized gains are reflected in the consolidated statements of income in operating revenues and the balance is primarily reflected in interest expense. For the year December 31, 2014 , $79 million of realized and unrealized losses are reflected in the consolidated statements of income in interest expense and the balance is primarily reflected in operating revenues. (b) 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 and, in 2016, a favorable change to a credit valuation adjustment. NEE's and FPL's policy is to recognize all transfers at the beginning of the reporting period. (c) For the years ended December 31, 2016 , 2015 and 2014 , $283 million , $289 million , and $328 million of unrealized gains are reflected in the consolidated statements of income in operating revenues and the balance is reflected in interest expense.
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, 2016 are as follows: Transaction Type Fair Value at December 31, 2016 Valuation Technique(s) Significant Unobservable Inputs Range Assets Liabilities (millions) Forward contracts - power $ 621 $ 206 Discounted cash flow Forward price (per MWh) $— — $91 Forward contracts - gas 27 10 Discounted cash flow Forward price (per MMBtu) $2 — $11 Forward contracts - other commodity related 7 1 Discounted cash flow Forward price (various) $(17) — $57 Options - power 43 10 Option models Implied correlations 1% — 100% Implied volatilities 9% — 296% Options - primarily gas 223 230 Option models Implied correlations 1% — 100% Implied volatilities 1% — 260% Full requirements and unit contingent contracts 279 55 Discounted cash flow Forward price (per MWh) $(20) — $220 Customer migration rate (a) —% — 20% Total $ 1,200 $ 512 ______________________ (a) Applies only to full requirements contracts.
Fair Value, by Balance Sheet Grouping	Fair Value of Financial Instruments Recorded at Other than Fair Value - The carrying amounts of cash equivalents, 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, 2016 December 31, 2015 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value (millions) NEE: Special use funds (a) $ 712 $ 712 $ 675 $ 675 Other investments - primarily notes receivable $ 526 $ 668 (b) $ 512 $ 722 (b) Long-term debt, including current maturities (c) $ 30,418 $ 31,623 (d) $ 28,897 $ 30,412 (d) FPL: Special use funds (a) $ 557 $ 557 $ 528 $ 528 Long-term debt, including current maturities $ 10,072 $ 11,211 (d) $ 10,020 $ 11,028 (d) ______________________ (a) Primarily represents investments accounted for under the equity method and loans not measured at fair value on a recurring basis. (b) Primarily classified as held to maturity. Fair values are primarily estimated using an income approach utilizing a discounted cash flow valuation technique based on certain observable yield curves and indices considering the credit profile of the borrower (Level 3). Notes receivable bear interest primarily at fixed rates and mature by 2029 . Notes receivable are considered impaired and placed in non-accrual status when it becomes probable that all amounts due cannot be collected in accordance with the contractual terms of the agreement. The assessment to place notes receivable in non-accrual status considers various credit indicators, such as credit ratings and market-related information. (c) Excludes debt totaling $373 million and $938 million , respectively, reflected in liabilities associated with assets held for sale on NEE's consolidated balance sheets for which the carrying amount approximates fair value. See Note 1 - Assets and Liabilities Associated with Assets Held for Sale. (d) As of December 31, 2016 and 2015 , for NEE, approximately $29,804 million and $18,031 million , respectively, is estimated using a market approach based on quoted market prices for the same or similar issues (Level 2); the balance is estimated using an income approach utilizing a discounted cash flow valuation technique, considering the current credit profile of the debtor (Level 3). For FPL, primarily estimated using quoted market prices for the same or similar issues (Level 2).
Available-for-sale Securities	Realized gains and losses and proceeds from the sale or maturity of available for sale securities are as follows: NEE FPL Years Ended December 31, Years Ended December 31, 2016 2015 2014 2016 2015 2014 (millions) Realized gains $ 116 $ 194 $ 211 $ 53 $ 70 $ 120 Realized losses $ 76 $ 87 $ 115 $ 44 $ 43 $ 94 Proceeds from sale or maturity of securities $ 3,400 $ 4,643 $ 4,092 $ 2,442 $ 3,724 $ 3,349 The unrealized gains on available for sale securities are as follows: NEE FPL December 31, December 31, 2016 2015 2016 2015 (millions) Equity securities $ 1,396 $ 1,166 $ 1,007 $ 863 Debt securities $ 22 $ 17 $ 17 $ 14 The 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, 2016 2015 2016 2015 (millions) Unrealized losses (a) $ 34 $ 51 $ 28 $ 45 Fair value $ 959 $ 1,129 $ 722 $ 861 ______________________ (a) Unrealized losses on available for sale debt securities in an unrealized loss position for greater than twelve months at December 31, 2016 and 2015 were not material to NEE or FPL.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
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, 2016 2015 2014 2016 2015 2014 (millions) Federal: Current $ 72 $ 10 $ — $ 72 $ 423 $ 240 Deferred 1,075 1,194 1,077 830 399 542 Total federal 1,147 1,204 1,077 902 822 782 State: Current 76 31 (29 ) 57 58 68 Deferred 160 (7 ) 128 92 77 60 Total state 236 24 99 149 135 128 Total income taxes $ 1,383 $ 1,228 $ 1,176 $ 1,051 $ 957 $ 910
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, 2016 2015 2014 2016 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % Increases (reductions) resulting from: State income taxes - net of federal income tax benefit 3.5 0.4 1.8 3.5 3.4 3.4 PTCs and ITCs - NEER (3.9 ) (4.1 ) (5.1 ) — — — Convertible ITCs - NEER (1.7 ) (0.8 ) (1.4 ) — — — Adjustments associated with Canadian assets (0.7 ) — 1.3 — — — Other - net (0.7 ) 0.3 0.7 (0.7 ) (1.7 ) (0.9 ) Effective income tax rate 31.5 % 30.8 % 32.3 % 37.8 % 36.7 % 37.5 %
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, 2016 2015 2016 2015 (millions) Deferred tax liabilities: Property-related $ 13,094 $ 12,204 $ 8,882 $ 8,040 Pension 454 455 502 480 Nuclear decommissioning trusts 253 219 — — Net unrealized gains on derivatives 581 528 — — Investments in partnerships and joint ventures 603 403 — — Other 1,272 1,196 796 695 Total deferred tax liabilities 16,257 15,005 10,180 9,215 Deferred tax assets and valuation allowance: Decommissioning reserves 454 438 401 386 Postretirement benefits 145 141 93 95 Net operating loss carryforwards 427 604 3 4 Tax credit carryforwards 3,059 2,916 — — ARO and accrued asset removal costs 777 759 699 697 Other 1,024 836 443 303 Valuation allowance (a) (269 ) (223 ) — — Net deferred tax assets 5,617 5,471 1,639 1,485 Net deferred income taxes $ 10,640 $ 9,534 $ 8,541 $ 7,730 ______________________ (a) Amount relates to a valuation allowance related to the solar projects in Spain, 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, 2016 2015 2016 2015 (millions) Noncurrent other assets $ 461 $ 293 $ — $ — Deferred income taxes - noncurrent liabilities (11,101 ) (9,827 ) (8,541 ) (7,730 ) Net deferred income taxes $ (10,640 ) $ (9,534 ) $ (8,541 ) $ (7,730 )
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, 2016 are as follows: Amount Expiration Dates (millions) Net operating loss carryforwards: Federal $ 165 2026-2036 State 174 2017-2036 Foreign 88 (a) 2017-2036 Net operating loss carryforwards $ 427 Tax credit carryforwards: Federal $ 2,697 2022-2036 State 362 (b) 2017-2044 Tax credit carryforwards $ 3,059 ______________________ (a) Includes $ 60 million of net operating loss carryforwards with an indefinite expiration period. (b) Includes $ 188 million of ITC carryforwards with an indefinite expiration period.

Jointly-Owned Electric Plants (

Jointly-Owned Electric Plants (Tables)	12 Months Ended
	Dec. 31, 2016
Jointly-Owned Electric Plants [Abstract]
Proportionate Ownership Interest In Jointly-Owned Facilities	NEE's and FPL's proportionate ownership interest in jointly-owned facilities is as follows: December 31, 2016 Ownership Interest Gross Investment (a) Accumulated Depreciation (a) Construction Work in Progress (millions) FPL: St. Lucie Unit No. 2 85 % $ 2,172 $ 815 $ 33 St. Johns River Power Park units and coal terminal 20 % $ 393 $ 208 $ — Scherer Unit No. 4 76 % $ 1,138 $ 395 $ 3 NEER: Duane Arnold 70 % $ 466 $ 146 $ 16 Seabrook 88.23 % $ 1,138 $ 271 $ 77 Wyman Station Unit No. 4 84.35 % $ 25 $ 3 $ — Corporate and Other: Transmission substation assets located in Seabrook, New Hampshire 88.23 % $ 76 $ 17 $ 3 ______________________ (a) Excludes nuclear fuel.

Business Acquisitions (Tables)

Business Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2016
Business Combinations [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	The following table summarizes the estimated fair value of assets acquired and liabilities assumed for the acquisition of the Texas pipeline business: Amounts Recognized (millions) Assets: Property, plant and equipment $ 806 Cash 1 Other receivables and current other assets 21 Noncurrent other assets (other intangible assets, see Note 1 - Goodwill and Other Intangible Assets) 720 Noncurrent other assets (goodwill, see Note 1 - Goodwill and Other Intangible Assets) 622 Total assets $ 2,170 Liabilities: Long-term debt, including current portion $ 706 Accounts payable and current other liabilities 46 Noncurrent other liabilities, primarily acquisition holdbacks 415 Total liabilities 1,167 Less noncontrolling interest at fair value 69 Total cash consideration $ 934

Investments in Partnerships a34

Investments in Partnerships and Joint Ventures (Tables)	12 Months Ended
	Dec. 31, 2016
Investments in Partnerships and Joint Ventures [Abstract]
Summarized combined information for principal operating entities	Summarized combined information for these principal entities is as follows: 2016 2015 (millions) Net income $ 264 $ 213 Total assets $ 4,502 $ 3,339 Total liabilities $ 1,364 $ 1,307 Partners'/members' equity $ 3,138 $ 2,032 NEER's share of underlying equity in the principal entities $ 1,423 $ 874 Difference between investment carrying amount and underlying equity in net assets (a) 65 (3 ) NEER's investment carrying amount for the principal entities $ 1,488 $ 871 ______________________ (a) Substantially all of the difference between the investment carrying amount and the underlying equity in net assets is being amortized over a 25-year period.

Common Shareholders' Equity (Ta

Common Shareholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	Earnings Per Share - The reconciliation of NEE's basic and diluted earnings per share attributable to NEE is as follows: Years Ended December 31, 2016 2015 2014 (millions, except per share amounts) Numerator - net income attributable to NEE $ 2,912 $ 2,752 $ 2,465 Denominator: Weighted-average number of common shares outstanding - basic 463.1 450.5 434.4 Equity units, performance share awards, stock options, forward sale agreement and restricted stock (a) 2.7 3.5 5.7 Weighted-average number of common shares outstanding - assuming dilution 465.8 454.0 440.1 Earnings per share attributable to NEE: Basic $ 6.29 $ 6.11 $ 5.67 Assuming dilution $ 6.25 $ 6.06 $ 5.60 ______________________ (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, 2016 was as follows: Shares Weighted- Average Grant Date Fair Value Per Share Restricted Stock: Nonvested balance, January 1, 2016 563,660 $ 89.60 Granted 291,422 $ 112.86 Vested (274,144 ) $ 85.62 Forfeited (24,290 ) $ 100.78 Nonvested balance, December 31, 2016 556,648 $ 103.26 Performance Share Awards: Nonvested balance, January 1, 2016 915,199 $ 81.90 Granted 604,686 $ 89.23 Vested (630,773 ) $ 69.40 Forfeited (54,679 ) $ 95.62 Nonvested balance, December 31, 2016 834,433 $ 95.76
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: 2016 2015 2014 Expected volatility (a) 16.37% 18.91% 20.32% Expected dividends 3.16% 3.11% 3.11% Expected term (years) (b) 7.0 7.0 7.0 Risk-free rate 1.50% 1.84% 2.17% ______________________ (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, 2016 was as follows: Shares Underlying Options Weighted- Average Exercise Price Per Share Weighted- Average Remaining Contractual Term (years) Aggregate Intrinsic Value (millions) Balance, January 1, 2016 2,866,501 $ 63.39 Granted 294,889 $ 111.67 Exercised (651,492 ) $ 55.37 Forfeited (4,690 ) $ 106.64 Balance, December 31, 2016 2,505,208 $ 71.08 5.4 $ 121 Exercisable, December 31, 2016 2,043,899 $ 62.90 4.7 $ 116
Schedule of Accumulated Other Comprehensive Income (Loss)	Accumulated Other Comprehensive Income (Loss) - The components of AOCI, net of tax, are as follows: Accumulated Other Comprehensive Income (Loss) Net Unrealized Gains (Losses) on Cash Flow Hedges Net Unrealized Gains (Losses) on Available for Sale Securities Defined Benefit Pension and Other Benefits Plans Net Unrealized Losses on Foreign Currency Translation Other Comprehensive Income (Loss) Related to Equity Method Investee Total (millions) Balances, December 31, 2013 $ (115 ) $ 197 $ 23 $ (33 ) $ (16 ) $ 56 Other comprehensive income (loss) before reclassifications (141 ) 62 (44 ) (25 ) (8 ) (156 ) Amounts reclassified from AOCI 98 (a) (41 ) (b) 1 — — 58 Net other comprehensive income (loss) (43 ) 21 (43 ) (25 ) (8 ) (98 ) Less other comprehensive loss attributable to noncontrolling interests (2 ) — — — — (2 ) Balances, December 31, 2014 (156 ) 218 (20 ) (58 ) (24 ) (40 ) Other comprehensive loss before reclassifications (88 ) (7 ) (42 ) (27 ) — (164 ) Amounts reclassified from AOCI 63 (a) (37 ) (b) — — — 26 Net other comprehensive loss (25 ) (44 ) (42 ) (27 ) — (138 ) Less other comprehensive loss attributable to noncontrolling interests (11 ) — — — — (11 ) Balances, December 31, 2015 (170 ) 174 (62 ) (85 ) (24 ) (167 ) Other comprehensive income (loss) before reclassifications — 69 (21 ) (5 ) 2 45 Amounts reclassified from AOCI 70 (a) (18 ) (b) — — — 52 Net other comprehensive income (loss) 70 51 (21 ) (5 ) 2 97 Less other comprehensive income attributable to noncontrolling interests — — — — — — Balances, December 31, 2016 $ (100 ) $ 225 $ (83 ) $ (90 ) $ (22 ) $ (70 ) ———————————— (a) Reclassified to interest expense and also to other - net in 2014 and 2015 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.

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Debt Issuances and Borrowings by Subsidiaries	Long-term debt consists of the following: December 31, 2016 2015 Maturity Balance Weighted- Balance Weighted- (millions) (millions) FPL: First mortgage bonds - fixed 2017 - 2044 $ 8,690 4.78 % $ 8,690 4.77 % Storm-recovery bonds - fixed (a) 2021 210 5.26 % 273 5.26 % Pollution control, solid waste disposal and industrial development revenue bonds - variable (b) 2020 - 2046 778 0.77 % 718 0.04 % Other long-term debt - variable (c) 2018 - 2019 450 1.66 % 400 1.11 % Other long-term debt - fixed 2016 - 2040 52 5.09 % 53 5.06 % Unamortized debt issuance costs and discount (108 ) (114 ) Total long-term debt of FPL 10,072 10,020 Less current maturities of long-term debt 367 64 Long-term debt of FPL, excluding current maturities 9,705 9,956 NEECH: Debentures - fixed (d) 2017 - 2023 4,100 2.87 % 3,100 3.15 % Debentures, related to NEE's equity units - fixed 2018 - 2021 2,200 1.88 % 1,200 1.98 % Junior subordinated debentures - primarily fixed (d) 2044 - 2076 3,460 5.40 % 2,978 5.84 % Japanese yen denominated senior notes - fixed (d) 2030 85 5.13 % 83 5.13 % Japanese yen denominated term loans - variable (c)(d) 2017 470 1.83 % 456 1.83 % Other long-term debt - fixed 2016 - 2044 924 2.45 % 1,307 4.55 % Other long-term debt - variable (c) 2016 - 2019 60 (e) 1.77 % 1,513 1.81 % Fair value hedge adjustment 8 24 Unamortized debt issuance costs and discount (101 ) (94 ) Total long-term debt of NEECH 11,206 10,567 Less current maturities of long-term debt 1,724 667 Long-term debt of NEECH, excluding current maturities 9,482 9,900 NEER: Senior secured limited-recourse bonds and notes - fixed 2017 - 2038 2,091 (f) 6.00 % 2,203 5.88 % Senior secured limited-recourse term loans - primarily variable (c)(d) 2016 - 2035 4,959 2.78 % 3,969 (g) 2.51 % Other long-term debt - primarily variable (c)(d) 2016 - 2040 2,262 2.97 % 2,273 2.72 % Unamortized debt issuance costs and premium - net (168 ) (131 ) Total long-term debt of NEER 9,144 8,314 Less current maturities of long-term debt 513 1,489 (h) Long-term debt of NEER, excluding current maturities 8,631 6,825 Total long-term debt $ 27,818 $ 26,681 ______________________ (a) Principal on the storm-recovery bonds is due on the final maturity date (the date by which the principal must be repaid to prevent a default) for each tranche, however, it is being paid semiannually and sequentially. (b) Tax exempt bonds that permit individual bond holders to tender the bonds for purchase at any time prior to maturity. In the event 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 the tax exempt bonds. As of December 31, 2016 , all tax exempt bonds tendered for purchase have been successfully remarketed. FPL's bank revolving line of credit facilities are available to support the purchase of tax exempt bonds. Variable interest rate is established at various intervals by the remarketing agent. (c) Variable rate is based on an underlying index plus a margin. (d) Interest rate contracts, primarily swaps, have been entered into with respect to certain of these debt issuances. Additionally, a foreign currency swap has been entered into with respect to the Japanese yen denominated term loans - variable. See Note 3. (e) Excludes debt totaling $373 million reflected in liabilities associated with assets held for sale on NEE's consolidated balance sheets. (f) Includes approximately $490 million of debt held by a wholly owned subsidiary of NEER and collateralized by a third-party note receivable held by that subsidiary. See Note 8 - NEER. (g) Excludes debt totaling $938 million reflected in liabilities associated with assets held for sale on NEE's consolidated balance sheets. See Note 1 - Assets and Liabilities Associated with Assets Held for Sale. (h) See Spain Solar Projects Debt Restructuring below.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligations [Abstract]
Asset retirement obligation, roll forward analysis	A rollforward of NEE's and FPL's AROs is as follows: FPL NEER NEE (millions) Balances, December 31, 2014 $ 1,355 $ 631 $ 1,986 Liabilities incurred 5 46 51 Accretion expense 73 43 116 Liabilities settled (20 ) (2 ) (22 ) Revision in estimated cash flows - net 409 (a) (71 ) (b) 338 Balances, December 31, 2015 1,822 647 2,469 Liabilities incurred 1 56 57 Accretion expense 91 47 138 Liabilities settled — (2 ) (2 ) Revision in estimated cash flows - net 5 69 (c) 74 Balances, December 31, 2016 $ 1,919 $ 817 $ 2,736 ______________________ (a) Primarily reflects the effect of revised cost estimates for decommissioning FPL's nuclear units consistent with the updated nuclear decommissioning studies approved by the FPSC. (b) Primarily reflects the effect of revised cost estimates for decommissioning NEER’s nuclear units and a change in assumptions relating to spent fuel costs, partly offset by increased escalation rates. (c) Primarily reflects the effect of revised cost estimates to dismantle certain of NEER’s wind and solar facilities.
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 as follows (see Note 4 - Special Use Funds): FPL NEER NEE (millions) Balances, December 31, 2016 $ 3,665 $ 1,769 $ 5,434 Balances, December 31, 2015 $ 3,430 $ 1,634 $ 5,064

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Schedule of Planned Capital Expenditures	At December 31, 2016 , estimated capital expenditures for 2017 through 2021 for which applicable internal approvals (and also, if required, FPSC approvals for FPL or regulatory approvals for acquisitions) have been received were as follows: 2017 2018 2019 2020 2021 Total (millions) FPL: Generation: (a) New (b) $ 1,385 $ 655 $ 485 $ 35 $ 5 $ 2,565 Existing 1,240 635 680 645 600 3,800 Transmission and distribution 2,190 2,010 2,860 2,475 2,945 12,480 Nuclear fuel 125 190 170 210 120 815 General and other 440 275 285 220 330 1,550 Total $ 5,380 $ 3,765 $ 4,480 $ 3,585 $ 4,000 $ 21,210 NEER: Wind (c) $ 570 $ 955 $ 705 $ 75 $ 25 $ 2,330 Solar (d) 80 75 15 — — 170 Nuclear, including nuclear fuel 240 250 230 225 245 1,190 Natural gas pipelines (e) 890 845 50 20 10 1,815 Other 335 55 40 40 35 505 Total $ 2,115 $ 2,180 $ 1,040 $ 360 $ 315 $ 6,010 Corporate and Other $ 45 $ 30 $ 85 $ 55 $ 35 $ 250 ______________________ (a) Includes AFUDC of approximately $ 81 million , $ 79 million , $46 million and $6 million for 2017 through 2020, respectively. (b) Includes land, generation structures, transmission interconnection and integration and licensing. (c) Consists of capital expenditures for new wind projects, repowering of existing wind projects and related transmission totaling approximately 2,760 MW. (d) Includes capital expenditures for new solar projects and related transmission totaling approximately 225 MW. (e) Includes capital expenditures for construction of three natural gas pipelines, including equity contributions associated with equity investments in joint ventures for two pipelines and AFUDC associated with the third pipeline. The natural gas pipelines are subject to certain conditions. See Contracts below.
Required Capacity and/or Minimum Payments	The required capacity and/or minimum payments under the contracts discussed above as of December 31, 2016 were estimated as follows: 2017 2018 2019 2020 2021 Thereafter (millions) FPL: Capacity charges (a) $ 75 $ 65 $ 50 $ 20 $ 20 $ 250 Minimum charges, at projected prices: (b) Natural gas, including transportation and storage (c) $ 1,305 $ 900 $ 900 $ 910 $ 905 $ 12,065 Coal, including transportation $ 125 $ 5 $ 5 $ — $ — $ — NEER $ 1,385 $ 1,380 $ 140 $ 90 $ 75 $ 285 Corporate and Other (d)(e) $ 45 $ 10 $ — $ 5 $ — $ — ______________________ (a) Capacity charges, substantially all of which are recoverable through the capacity clause, totaled approximately $ 175 million , $ 434 million and $ 485 million for the years ended December 31, 2016, 2015 and 2014 , respectively. Energy charges, which are recoverable through the fuel clause, totaled approximately $ 126 million , $ 262 million and $ 299 million for the years ended December 31, 2016, 2015 and 2014 , respectively. (b) Recoverable through the fuel clause. (c) Includes approximately $ 200 million , $ 295 million , $ 290 million , $360 million , $390 million and $ 7,495 million in 2017, 2018, 2019, 2020, 2021 and thereafter, respectively, of firm commitments, subject to certain conditions as noted above, related to the natural gas transportation agreements with Sabal Trail and Florida Southeast Connection. (d) Includes an approximately $30 million commitment to invest in clean power and technology businesses primarily in 2017. (e) Excludes approximately $263 million and $148 million in 2017 and 2018, respectively, of joint obligations of NEECH and NEER which are included in the NEER amounts above.

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Segment Information	NEE's segment information is as follows: 2016 2015 2014 FPL NEER (a) Corp. and Other NEE Consoli- dated FPL NEER (a) Corp. and Other NEE Consoli- dated FPL NEER (a) Corp. and Other NEE Consoli- dated (millions) Operating revenues $ 10,895 $ 4,893 $ 367 $ 16,155 $ 11,651 $ 5,444 $ 391 $ 17,486 $ 11,421 $ 5,196 $ 404 $ 17,021 Operating expenses - net $ 7,737 $ 3,419 $ 391 $ 11,547 $ 8,674 $ 3,865 $ 315 $ 12,854 $ 8,593 $ 3,727 $ 317 $ 12,637 Interest expense $ 456 $ 732 $ (95 ) $ 1,093 $ 445 $ 625 $ 141 $ 1,211 $ 439 $ 667 $ 155 $ 1,261 Interest income $ 2 $ 34 $ 46 $ 82 $ 7 $ 28 $ 51 $ 86 $ 3 $ 26 $ 51 $ 80 Depreciation and amortization $ 1,651 $ 1,366 $ 60 $ 3,077 $ 1,576 $ 1,183 $ 72 $ 2,831 $ 1,432 $ 1,051 $ 68 $ 2,551 Equity in earnings (losses) of equity method investees $ — $ 119 $ 29 $ 148 $ — $ 103 $ 4 $ 107 $ — $ 95 $ (2 ) $ 93 Income tax expense (benefit) (b) $ 1,051 $ 242 $ 90 $ 1,383 $ 957 $ 289 $ (18 ) $ 1,228 $ 910 $ 283 $ (17 ) $ 1,176 Net income (loss) $ 1,727 $ 1,218 $ 60 $ 3,005 $ 1,648 $ 1,102 $ 12 $ 2,762 $ 1,517 $ 993 $ (41 ) $ 2,469 Net income (loss) attributable to NEE $ 1,727 $ 1,125 $ 60 $ 2,912 $ 1,648 $ 1,092 $ 12 $ 2,752 $ 1,517 $ 989 $ (41 ) $ 2,465 Capital expenditures, independent power and other investments and nuclear fuel purchases $ 3,934 $ 5,521 $ 181 $ 9,636 $ 3,633 $ 4,661 $ 83 $ 8,377 $ 3,241 $ 3,701 $ 75 $ 7,017 Property, plant and equipment $ 48,313 $ 37,644 $ 1,056 $ 87,013 $ 45,383 $ 33,340 $ 1,607 $ 80,330 $ 41,938 $ 30,178 $ 1,523 $ 73,639 Accumulated depreciation and amortization $ 12,304 $ 7,655 $ 142 $ 20,101 $ 11,862 $ 6,640 $ 442 $ 18,944 $ 11,282 $ 6,268 $ 384 $ 17,934 Total assets $ 45,501 $ 41,743 $ 2,749 $ 89,993 $ 42,523 $ 37,647 $ 2,309 $ 82,479 $ 39,222 $ 32,896 $ 2,487 $ 74,605 Investment in equity method investees $ — $ 1,661 $ 106 $ 1,767 $ — $ 983 $ 80 $ 1,063 $ — $ 617 $ 46 $ 663 _________________________ (a) Interest expense allocated from NEECH is based on a deemed capital structure of 70% debt. For this purpose, the deferred credit associated with differential membership interests sold by NEER subsidiaries is included with debt. Residual NEECH corporate interest expense is included in Corporate and Other. (b) NEER includes PTCs that were recognized based on its tax sharing agreement with NEE. See Note 1 - Income Taxes.

Summarized Financial Informat40

Summarized Financial Information of NEECH (Tables)	12 Months Ended
	Dec. 31, 2016
Summarized Financial Information [Abstract]
Condensed Consolidating Statements of Income	Condensed Consolidating Statements of Income Year Ended Year Ended Year Ended NEE NEECH Other (a) NEE NEE NEECH Other (a) NEE NEE NEECH Other (a) NEE (millions) Operating revenues $ — $ 5,283 $ 10,872 $ 16,155 $ — $ 5,849 $ 11,637 $ 17,486 $ — $ 5,614 $ 11,407 $ 17,021 Operating expenses - net (20 ) (3,663 ) (7,864 ) (11,547 ) (17 ) (4,142 ) (8,695 ) (12,854 ) (19 ) (4,039 ) (8,579 ) (12,637 ) Interest expense (1 ) (636 ) (456 ) (1,093 ) (4 ) (764 ) (443 ) (1,211 ) (6 ) (819 ) (436 ) (1,261 ) Equity in earnings of subsidiaries 2,956 — (2,956 ) — 2,754 — (2,754 ) — 2,494 — (2,494 ) — Other income - net 5 793 75 873 1 498 70 569 1 487 34 522 Income (loss) before income taxes 2,940 1,777 (329 ) 4,388 2,734 1,441 (185 ) 3,990 2,470 1,243 (68 ) 3,645 Income tax expense (benefit) 28 354 1,001 1,383 (18 ) 299 947 1,228 5 262 909 1,176 Net income (loss) 2,912 1,423 (1,330 ) 3,005 2,752 1,142 (1,132 ) 2,762 2,465 981 (977 ) 2,469 Less net income attributable to noncontrolling interests — 93 — 93 — 10 — 10 — 4 — 4 Net income (loss) attributable to NEE $ 2,912 $ 1,330 $ (1,330 ) $ 2,912 $ 2,752 $ 1,132 $ (1,132 ) $ 2,752 $ 2,465 $ 977 $ (977 ) $ 2,465 ______________________ (a) Represents primarily FPL and consolidating adjustments.
Condensed Consolidating Statements of Comprehensive Income	Condensed Consolidating Statements of Comprehensive Income Year Ended Year Ended Year Ended NEE NEECH Other (a) NEE NEE NEECH Other (a) NEE NEE NEECH Other (a) NEE (millions) Comprehensive income (loss) attributable to NEE $ 3,009 $ 1,448 $ (1,448 ) $ 3,009 $ 2,625 $ 1,049 $ (1,049 ) $ 2,625 $ 2,369 $ 924 $ (924 ) $ 2,369 ______________________ (a) Represents primarily FPL and consolidating adjustments.
Condensed Consolidating Balance Sheets	Condensed Consolidating Balance Sheets December 31, 2016 December 31, 2015 NEE (Guaran- NEECH Other (a) NEE NEE (Guaran- NEECH Other (a) NEE (millions) PROPERTY, PLANT AND EQUIPMENT Electric plant in service and other property $ 28 $ 38,671 $ 48,314 $ 87,013 $ 27 $ 34,921 $ 45,382 $ 80,330 Accumulated depreciation and amortization (18 ) (7,778 ) (12,305 ) (20,101 ) (16 ) (7,067 ) (11,861 ) (18,944 ) Total property, plant and equipment - net 10 30,893 36,009 66,912 11 27,854 33,521 61,386 CURRENT ASSETS Cash and cash equivalents 1 1,258 33 1,292 — 546 25 571 Receivables 88 1,615 736 2,439 90 1,510 665 2,265 Other 2 1,877 1,799 3,678 4 2,443 1,512 3,959 Total current assets 91 4,750 2,568 7,409 94 4,499 2,202 6,795 OTHER ASSETS Investment in subsidiaries 24,323 — (24,323 ) — 22,544 — (22,544 ) — Other 867 8,992 5,813 15,672 823 7,790 5,685 14,298 Total other assets 25,190 8,992 (18,510 ) 15,672 23,367 7,790 (16,859 ) 14,298 TOTAL ASSETS $ 25,291 $ 44,635 $ 20,067 $ 89,993 $ 23,472 $ 40,143 $ 18,864 $ 82,479 CAPITALIZATION Common shareholders' equity $ 24,341 $ 7,699 $ (7,699 ) $ 24,341 $ 22,574 $ 6,990 $ (6,990 ) $ 22,574 Noncontrolling interests — 990 — 990 — 538 — 538 Long-term debt — 18,112 9,706 27,818 — 16,725 9,956 26,681 Total capitalization 24,341 26,801 2,007 53,149 22,574 24,253 2,966 49,793 CURRENT LIABILITIES Debt due within one year — 2,237 785 3,022 — 2,786 220 3,006 Accounts payable 1 2,668 778 3,447 4 1,919 606 2,529 Other 231 2,624 1,595 4,450 252 3,003 1,317 4,572 Total current liabilities 232 7,529 3,158 10,919 256 7,708 2,143 10,107 OTHER LIABILITIES AND DEFERRED CREDITS Asset retirement obligations — 816 1,920 2,736 — 647 1,822 2,469 Deferred income taxes 82 3,002 8,017 11,101 157 2,396 7,274 9,827 Other 636 6,487 4,965 12,088 485 5,139 4,659 10,283 Total other liabilities and deferred credits 718 10,305 14,902 25,925 642 8,182 13,755 22,579 COMMITMENTS AND CONTINGENCIES TOTAL CAPITALIZATION AND LIABILITIES $ 25,291 $ 44,635 $ 20,067 $ 89,993 $ 23,472 $ 40,143 $ 18,864 $ 82,479 ______________________ (a) Represents primarily FPL and consolidating adjustments.
Condensed Consolidating Statements of Cash Flows	Condensed Consolidating Statements of Cash Flows Year Ended Year Ended Year Ended NEE (Guar- antor) NEECH Other (a) NEE Consoli- dated NEE (Guar- antor) NEECH Other (a) NEE Consoli- dated NEE (Guar- antor) NEECH Other (a) NEE Consoli- dated (millions) NET CASH PROVIDED BY OPERATING ACTIVITIES $ 1,897 $ 2,171 $ 2,268 $ 6,336 $ 1,659 $ 2,488 $ 1,969 $ 6,116 $ 1,615 $ 1,976 $ 1,909 $ 5,500 CASH FLOWS FROM INVESTING ACTIVITIES Capital expenditures, independent power and other investments and nuclear fuel purchases (1 ) (5,701 ) (3,934 ) (9,636 ) — (4,744 ) (3,633 ) (8,377 ) (1 ) (3,741 ) (3,275 ) (7,017 ) Capital contributions from NEE (745 ) — 745 — (1,480 ) — 1,480 — (912 ) — 912 — Cash grants under the Recovery Act — 335 — 335 — 8 — 8 — 343 — 343 Sale of independent power and other investments of NEER — 658 — 658 — 52 — 52 — 307 — 307 Proceeds from sale or maturity of securities in special use funds and other investments — 1,281 2,495 3,776 — 1,120 3,731 4,851 — 1,272 3,349 4,621 Purchases of securities in special use funds and other investments — (1,323 ) (2,506 ) (3,829 ) — (1,190 ) (3,792 ) (4,982 ) — (1,321 ) (3,446 ) (4,767 ) Proceeds from the sale of a noncontrolling interest in subsidiaries — 645 — 645 — 345 — 345 — 438 — 438 Other - net — (40 ) (19 ) (59 ) — 106 (8 ) 98 10 (64 ) (232 ) (286 ) Net cash used in investing activities (746 ) (4,145 ) (3,219 ) (8,110 ) (1,480 ) (4,303 ) (2,222 ) (8,005 ) (903 ) (2,766 ) (2,692 ) (6,361 ) CASH FLOWS FROM FINANCING ACTIVITIES Issuances of long-term debt — 5,349 308 5,657 — 4,689 1,083 5,772 — 4,057 997 5,054 Retirements of long-term debt — (3,048 ) (262 ) (3,310 ) — (3,421 ) (551 ) (3,972 ) — (4,395 ) (355 ) (4,750 ) Proceeds from differential membership investors — 1,859 — 1,859 — 761 — 761 — 978 — 978 Proceeds from other short-term debt — — 500 500 — 1,125 100 1,225 — 500 — 500 Repayments of other short-term debt — (212 ) (450 ) (662 ) — (813 ) — (813 ) — (500 ) — (500 ) Net change in commercial paper — (318 ) 212 (106 ) — 318 (1,086 ) (768 ) — (487 ) 938 451 Issuances of common stock - net 537 — — 537 1,298 — — 1,298 633 — — 633 Dividends on common stock (1,612 ) — — (1,612 ) (1,385 ) — — (1,385 ) (1,261 ) — — (1,261 ) Dividends to NEE — (650 ) 650 — — (698 ) 698 — — 812 (812 ) — Other - net (75 ) (294 ) 1 (368 ) (92 ) (162 ) 19 (235 ) (84 ) (31 ) 10 (105 ) Net cash provided by (used in) financing activities (1,150 ) 2,686 959 2,495 (179 ) 1,799 263 1,883 (712 ) 934 778 1,000 Net increase (decrease) in cash and cash equivalents 1 712 8 721 — (16 ) 10 (6 ) — 144 (5 ) 139 Cash and cash equivalents at beginning of year — 546 25 571 — 562 15 577 — 418 20 438 Cash and cash equivalents at end of year $ 1 $ 1,258 $ 33 $ 1,292 $ — $ 546 $ 25 $ 571 $ — $ 562 $ 15 $ 577 ______________________ (a) Represents primarily FPL and consolidating adjustments.

Quarterly Data (Unaudited) (Tab

Quarterly Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2016
Quarterly Data (Unaudited) [Abstract]
Condensed Consolidated Quarterly Financial Information	Condensed consolidated quarterly financial information is as follows: March 31 (a) June 30 (a) September 30 (a) December 31 (a) (millions, except per share amounts) NEE: 2016 Operating revenues (b) $ 3,835 $ 3,817 $ 4,805 $ 3,699 Operating income (b) $ 1,234 $ 1,169 $ 1,279 $ 926 Net income (b) $ 654 (c) $ 544 $ 789 $ 1,017 Net income attributable to NEE (b) $ 653 (c) $ 540 $ 753 $ 966 Earnings per share attributable to NEE - basic (d) $ 1.42 (c) $ 1.17 $ 1.63 $ 2.07 Earnings per share attributable to NEE - assuming dilution (d) $ 1.41 (c) $ 1.16 $ 1.62 $ 2.06 Dividends per share $ 0.87 $ 0.87 $ 0.87 $ 0.87 High-low common stock sales prices $119.37 - $102.20 $130.43 - $112.44 $131.98 - $120.22 $128.46 - $110.49 2015 Operating revenues (b) $ 4,104 $ 4,358 $ 4,954 $ 4,069 Operating income (b) $ 1,129 $ 1,146 $ 1,481 $ 876 Net income (b) $ 650 $ 720 $ 882 $ 510 Net income attributable to NEE (b) $ 650 $ 716 $ 879 $ 507 Earnings per share attributable to NEE - basic (d) $ 1.47 $ 1.61 $ 1.94 $ 1.10 Earnings per share attributable to NEE - assuming dilution (d) $ 1.45 $ 1.59 $ 1.93 $ 1.10 Dividends per share $ 0.77 $ 0.77 $ 0.77 $ 0.77 High-low common stock sales prices $112.64 - $97.48 $106.63 - $97.23 $109.98 - $93.74 $105.85 - $95.84 FPL: 2016 Operating revenues (b) $ 2,303 $ 2,750 $ 3,283 $ 2,558 Operating income (b) $ 714 $ 828 $ 921 $ 694 Net income (b) $ 393 $ 448 $ 515 $ 371 2015 Operating revenues (b) $ 2,541 $ 2,996 $ 3,274 $ 2,839 Operating income (b) $ 667 $ 780 $ 855 $ 674 Net income (b) $ 359 $ 435 $ 489 $ 365 ______________________ (a) In the opinion of NEE and FPL management, all adjustments, which consist of normal recurring accruals necessary to present a fair statement of the amounts shown for such periods, have been made. Results of operations for an interim period generally will not give a true indication of results for the year. (b) The sum of the quarterly amounts may not equal the total for the year due to rounding. (c) Amounts were restated to reflect the adoption in the second quarter of 2016 of an accounting standards update resulting in an increase to net income and net income attributable to NEE of $17 million , and an increase to earnings per share attributable to NEE, basic and assuming dilution, of $0.04 . See Note 10 - Stock-Based Compensation. (d) The sum of the quarterly amounts may not equal the total for the year due to rounding and changes in weighted-average number of common shares outstanding.

Summary of Significant Accoun42

Summary of Significant Accounting and Reporting Policies (Details) customer in Millions, account in Millions	Jun. 30, 2019USD ($)MW	Jan. 01, 2018USD ($)	Jan. 01, 2017USD ($)	Jul. 01, 2014USD ($)shares	Feb. 28, 2017USD ($)	Jan. 31, 2017USD ($)	Oct. 31, 2016customer	Sep. 30, 2016USD ($)	Oct. 31, 2016USD ($)	Mar. 31, 2017USD ($)	Dec. 31, 2016USD ($)accountMW	Dec. 31, 2016USD ($)accountunitprojectMWshares	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2020USD ($)kWh$ / kWMW	Dec. 31, 2016USD ($)accountMW	Oct. 31, 2015USD ($)	Sep. 30, 2015USD ($)
Basis of Presentation [Abstract]
Approximate number of customer accounts | account											4.9	4.9				4.9
Noncontrolling Interest [Abstract]
Profit Sharing Liability, net of Amortization											$ 757,000,000	$ 757,000,000	$ 447,000,000			$ 757,000,000
Electric Plant, Depreciation and Amortization [Abstract]
Convertible ITCs												2,100,000,000	1,800,000,000
Convertible ITCs included in other receivables											289,000,000	289,000,000	207,000,000			289,000,000
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Asset Retirement Obligation											2,736,000,000	2,736,000,000	2,469,000,000	$ 1,986,000,000		2,736,000,000
Restricted Cash [Abstract]
Restricted cash, current											311,000,000	311,000,000	244,000,000			311,000,000
Income Taxes [Abstract]
Revenue equivalent of the difference in accumulated deferred income taxes computed under accounting rules, as compared to regulatory accounting rules											289,000,000	289,000,000	283,000,000			289,000,000
Unrecognized tax benefits that impact annual effective income tax rate											$ 40,000,000	$ 40,000,000				$ 40,000,000
NextEra Energy Partners [Member]
Noncontrolling Interest [Abstract]
Number of projects | project												22
Assets and Liabilities Associated with Assets Held for Sale [Abstract]
Renewable Energy Assets, Power Generation Capacity | MW											2,787	2,787				2,787
Partnership Interest [Member]
Noncontrolling Interest [Abstract]
Partners' Capital Account, Units, Sold in Public Offering | shares				18,687,500
Partners' Capital Account, Public Sale of Units Net of Offering Costs				$ 438,000,000
FPL [Member]
Revenues and Rates [Abstract]
Unbilled Receivables, Current											$ 261,000,000	$ 261,000,000	246,000,000			$ 261,000,000
Franchise fees and gross receipts taxes												700,000,000	722,000,000	716,000,000
Surcharges related to storm-recovery												$ 119,000,000	115,000,000	109,000,000
FPSC rate orders [Abstract]
Regulatory return on common equity (in hundredths)																10.50%
Original Reserve Amount That May Be Amortized Under the 2012 Rate Agreement																$ 400,000,000
Regulatory return on common equity range (in hundredths)																1.00%
Increase in base rate revenues																$ 350,000,000
Earned regulatory ROE threshold below which retail base rate relief may be sought (in hundredths)																9.50%
Earned regulatory ROE threshold above which retail base rate reduction may be sought (in hundredths)																11.50%
Percentage of Certain Gains Received by Customers From Base Rate Revenue																100.00%
Electric Plant, Depreciation and Amortization [Abstract]
Percentage of electric generating assets to gross investment in electric utility plant in service (in hundredths)											50.00%	50.00%				50.00%
Percentage of electric transmission assets to gross investment in electric utility plant in service (in hundredths)											11.00%	11.00%				11.00%
Percentage of electric distribution assets to gross investment in electric utility plant in service (in hundredths)											33.00%	33.00%				33.00%
Percentage of general facilities assets to gross investment in electric utility plant in service (in hundredths)											6.00%	6.00%				6.00%
Convertible ITCs												$ 147,000,000	153,000,000
Maximum interval between depreciation studies performed and filed with the FPSC (in years)												4
Amount of reserve (reversal) amortization recognized												$ 13,000,000	$ (15,000,000)	$ (33,000,000)
FPL's composite depreciation rate for electric plant in service (in hundredths)												3.40%	3.30%	3.30%
Construction Activity [Abstract]
Threshold of plant in service balance at which AFUDC may be recorded (in hundredths)												0.50%
AFUDC capitalization rate for FPL (in hundredths)												6.34%	6.34%	6.34%
AFUDC capitalized for FPL												$ 97,000,000	$ 88,000,000	$ 50,000,000
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Maximum interval between nuclear decommissioning studies submitted to the FPSC for approval (in years)												5 years
For FPL, number of nuclear units | unit												4
FPL's portion of the ultimate costs of nuclear decommissioning											$ 7,500,000,000	$ 7,500,000,000				$ 7,500,000,000
FPL's Ultimate costs of nuclear decommissioning, in current year dollars											3,000,000,000	3,000,000,000				3,000,000,000
FPL's fund earnings on decommissioning funds												$ 102,000,000	96,000,000	91,000,000
Maximum interval between plant dismantlement studies submitted to the FPSC for approval (in years)												4 years
Plant Dismantlement Approved Expense Prior Dismantlement Study												$ 18,000,000
Plant Dismantlement Approved Expense Effective January 2017												26,000,000
Ultimate Costs Of Plant Dismantlement											1,300,000,000	1,300,000,000				1,300,000,000
Ultimate Costs Of Plant Dismantlement In Current Year Dollars											480,000,000	480,000,000				480,000,000
Asset Retirement Obligation											1,919,000,000	1,919,000,000	1,822,000,000	1,355,000,000		1,919,000,000
Major Maintenance Costs [Abstract]
Accrued liability for nuclear maintenance costs											65,000,000	65,000,000	48,000,000			65,000,000
Nuclear maintenance costs												89,000,000	90,000,000	76,000,000
Restricted Cash [Abstract]
Restricted cash, current											120,000,000	120,000,000	75,000,000			120,000,000
Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve [Abstract]
Storm fund included in special use funds													74,000,000
Proceeds from withdraw of storm funds											74,000,000
Customers that lost electrical service | customer							1.2
Eligible storm restoration costs									$ 315,000,000
Storm and property insurance reserve prior to Hurricane Hermine and Hurricane Matthew								$ 112,000,000
Portion absorbed by Hurricane Hermine for property and insurance reserve								$ 20,000,000
Amount of storm costs that exceeded storm reserve											203,000,000	203,000,000				203,000,000
Income Taxes [Abstract]
Revenue equivalent of the difference in accumulated deferred income taxes computed under accounting rules, as compared to regulatory accounting rules											266,000,000	266,000,000	268,000,000			266,000,000
Accumulated Deferred Investment Tax Credit											123,000,000	123,000,000	3,000,000			123,000,000
Deferred income tax benefit associated with convertible ITCs												46,000,000	48,000,000
NEER [Member]
Electric Plant, Depreciation and Amortization [Abstract]
Net book value of assets serving as collateral											15,500,000,000	15,500,000,000				15,500,000,000
Construction Activity [Abstract]
Project development costs of NextEra Energy Resources											$ 193,000,000	193,000,000	133,000,000			$ 193,000,000
Interest capitalized on construction projects of NextEra Energy Resources												$ 107,000,000	100,000,000	104,000,000
Deemed capital structure of NextEra Energy Resources (in hundredths)											70.00%	70.00%				70.00%
Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs [Abstract]
Asset Retirement Obligation											$ 817,000,000	$ 817,000,000	647,000,000	631,000,000		$ 817,000,000
Ultimate Costs Of Nuclear Decommissioning For Wholly Owned Indirect Subsidiary											11,800,000,000	11,800,000,000				11,800,000,000
Ultimate Costs Of Nuclear Decommissioning In Current Year Dollars For Wholly Owned Indirect Subsidiary											2,000,000,000	2,000,000,000				2,000,000,000
Ultimate costs to dismantle wind and solar facilities												$ 1,800,000,000
Effective period for Seabrook's decommissioning funding plan (in years)												4 years
Major Maintenance Costs [Abstract]
Capitalized major maintenance costs											$ 69,000,000	$ 69,000,000	97,000,000			$ 69,000,000
Major maintenance costs												$ 74,000,000	$ 79,000,000	$ 81,000,000
NEER [Member] | Variable Interest Entities Wind Primary Beneficiary [Member]
Variable Interest Entities [Abstract]
Wind Electric Generating Facility Capability | MW												6,847
NEER [Member] | Photovoltaic Solar Facility [Member]
Variable Interest Entities [Abstract]
Solar Generating Facility Capability | MW												374
Forecast [Member] | FPL [Member]
FPSC rate orders [Abstract]
Regulatory return on common equity (in hundredths)															10.55%
Increase in base rate revenues	$ 200,000,000	$ 211,000,000	$ 400,000,000
Earned regulatory ROE threshold below which retail base rate relief may be sought (in hundredths)															9.60%
Earned regulatory ROE threshold above which retail base rate reduction may be sought (in hundredths)															11.60%
Installed solar cost cap, per kilowatt | $ / kW															1,750
Maximum Amount Of Depreciation Reserve That May Be Amortized															$ 1,000,000,000
Reserve amount remaining under 2012 rate agreement that may be amortized															250,000,000
Maximum Storm Surcharge															4
Threshold Of Storm Restoration Costs In Any Given Calendar Year At Which Surcharge May Be Increased															800,000,000
Threshold Of Storm Restoration Costs In Any Given Calendar Year At Which Surcharge May Be Increased, Amount Above Which May Be Recovered															$ 400,000,000
Increment Of Usage In Kwh On Which Storm Surcharge Is Based | kWh															1,000
Assets and Liabilities Associated with Assets Held for Sale [Abstract]
Renewable Energy Assets, Power Generation Capacity | MW	1,750														300
Wind plants [Member] | NEER [Member]
Electric Plant, Depreciation and Amortization [Abstract]
Percentage of gross depreciable assets by plant type											62.00%	62.00%	62.00%			62.00%
Nuclear Plant [Member] | NEER [Member]
Electric Plant, Depreciation and Amortization [Abstract]
Percentage of gross depreciable assets by plant type											10.00%	10.00%	11.00%			10.00%
natural gas plant [Member] | NEER [Member]
Electric Plant, Depreciation and Amortization [Abstract]
Percentage of gross depreciable assets by plant type											1.00%	1.00%	3.00%			1.00%
Solar plants [Member] | NEER [Member]
Electric Plant, Depreciation and Amortization [Abstract]
Percentage of gross depreciable assets by plant type											14.00%	14.00%	9.00%			14.00%
Oil and Gas Properties [Member] | NEER [Member]
Electric Plant, Depreciation and Amortization [Abstract]
Percentage of gross depreciable assets by plant type											8.00%	8.00%	7.00%			8.00%
Minimum [Member] | Forecast [Member] | FPL [Member]
FPSC rate orders [Abstract]
Regulatory return on common equity (in hundredths)															9.60%
Minimum [Member] | wind, natural gas and solar plants [Member] | NEER [Member]
Electric Plant, Depreciation and Amortization [Abstract]
Property, plant and equipment, estimated useful lives (in years)												25 years
Minimum [Member] | Nuclear Plant [Member] | NEER [Member]
Electric Plant, Depreciation and Amortization [Abstract]
Property, plant and equipment, estimated useful lives (in years)												25 years
Maximum [Member] | Forecast [Member] | FPL [Member]
FPSC rate orders [Abstract]
Regulatory return on common equity (in hundredths)															11.60%
Maximum [Member] | wind, natural gas and solar plants [Member] | NEER [Member]
Electric Plant, Depreciation and Amortization [Abstract]
Property, plant and equipment, estimated useful lives (in years)												30 years
Maximum [Member] | Nuclear Plant [Member] | NEER [Member]
Electric Plant, Depreciation and Amortization [Abstract]
Property, plant and equipment, estimated useful lives (in years)												47 years
Indirect Wholly-Owned Subsidiary [Member] | Partnership Interest [Member]
Noncontrolling Interest [Abstract]
Payments to Acquire Limited Partnership Interests				$ 288,000,000
NEP OpCo [Member]
Noncontrolling Interest [Abstract]
Partners' Capital Account, Units, Retained | shares				74,440,000
Noncontrolling interest ownership percentage				79.90%							65.20%	65.20%				65.20%
NEP OpCo [Member] | Partnership Interest [Member]
Noncontrolling Interest [Abstract]
Payments to Acquire Limited Partnership Interests				$ 150,000,000
HEI [Member]
Terminated Merger [Abstract]
merger termination fee											$ 90,000,000	$ 90,000,000				$ 90,000,000
Out of pocket expenses reimbursed to HEI											5,000,000	$ 5,000,000				5,000,000
Common Units [Member] | NextEra Energy Partners [Member]
Noncontrolling Interest [Abstract]
Common units sold during period | shares												35,527,435
Common Units [Member] | Subsidiary of NextEra Energy [Member] | NEP OpCo [Member]
Noncontrolling Interest [Abstract]
Common units sold during period | shares												27,000,000
Common Units [Member] | NEP OpCo [Member]
Noncontrolling Interest [Abstract]
Stock Purchase Program, Authorized Amount																	$ 150,000,000
Stock Purchase Program, Amount Purchased											36,000,000	$ 36,000,000				36,000,000
Common Units [Member] | NextEra Energy Partners [Member] | NEP OpCo [Member]
Noncontrolling Interest [Abstract]
Common units sold during period | shares												35,527,435
Coal Fired Generation Facility [Member] | FPL [Member]
Regulated Operations [Abstract]
Termination of Purchased Power Agreement and Purchase Price of Generation Facility																		$ 521,000,000
Regulatory Assets																		$ 847,000,000
Regulatory Asset, Amortization Period												9 years
Regulatory Assets, Net of Amortization											$ 726,000,000	$ 726,000,000	$ 817,000,000			$ 726,000,000
Revised Reserve Amount That May Be Amortized Under the 2012 Rate Agreement Less Reduction Related to Settlement												370,000,000
Reduction To Reserve Amount Related to Settlement That May Be Amortized Under the 2012 Rate Agreement												$ 30,000,000
Subsequent Event [Member] | FPL [Member]
Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve [Abstract]
Amount approved to replenish reserve amount					$ 117,000,000
Natural Gas Generation Facilities [Member] [Member] | Subsidiary of NEER [Member]
Assets and Liabilities Associated with Assets Held for Sale [Abstract]
Renewable Energy Assets, Power Generation Capacity | MW											840	840				840
Proceeds from Divestiture of Interest in Consolidated Subsidiaries												$ 260,000,000
Gain on sale of ownership interest in subsidiary												191,000,000
Gain on sale of ownership interest in subsidiary after tax												$ 113,000,000
Merchant Natural Gas Generation Facilities [Member] | Subsidiary of NEER [Member]
Assets and Liabilities Associated with Assets Held for Sale [Abstract]
Renewable Energy Assets, Power Generation Capacity | MW											2,884	2,884				2,884
Proceeds from Divestiture of Interest in Consolidated Subsidiaries												$ 456,000,000
Gain on sale of ownership interest in subsidiary												254,000,000
Gain on sale of ownership interest in subsidiary after tax												106,000,000
FPL FiberNet [Member] | Forecast [Member] | Indirect Wholly-Owned Subsidiary [Member]
Assets and Liabilities Associated with Assets Held for Sale [Abstract]
Gain on sale of ownership interest in subsidiary										$ 1,100,000,000
Gain on sale of ownership interest in subsidiary after tax										$ 700,000,000
FPL FiberNet [Member] | Subsequent Event [Member] | Indirect Wholly-Owned Subsidiary [Member]
Assets and Liabilities Associated with Assets Held for Sale [Abstract]
Proceeds from Divestiture of Interest in Consolidated Subsidiaries						$ 1,100,000,000
Repayment of long term debt						$ 370,000,000
Taxes other than income taxes and other - net [Member]
Noncontrolling Interest [Abstract]
Amortization of Deferred Gain on Sale of Property												$ 37,000,000

Summary of Significant Accoun43

Summary of Significant Accounting and Reporting Policies (Regulatory Assets and Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Current:
Derivatives	$ 0	$ 218
Storm reserve deficiency	203	0
Other	321	285
Total	524	503
Noncurrent:
Purchased power agreement termination	636	726
Other	1,258	1,052
Total	1,894	1,778
Current:
Derivatives	208	0
Other	91	14
Total	299	14
Noncurrent:
Accrued asset removal costs	1,956	1,930
Asset retirement obligation regulatory expense difference	2,294	2,182
Other	656	494
Total	4,906	4,606
FPL [Member]
Current:
Derivatives	0	218
Storm reserve deficiency	203	0
Other	321	284
Total	524	502
Noncurrent:
Purchased power agreement termination	636	726
Other	937	787
Total	1,573	1,513
Current:
Derivatives	208	0
Other	86	12
Total	294	12
Noncurrent:
Accrued asset removal costs	1,944	1,921
Asset retirement obligation regulatory expense difference	2,294	2,182
Other	655	492
Total	$ 4,893	$ 4,595

Summary of Significant Accoun44

Summary of Significant Accounting and Reporting Policies (Goodwill and Intangible Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Goodwill and Intangible Assets [Line Items]
Goodwill	$ 779	$ 778
Other intangible assets not subject to amortization, primarily land easements	143	143
Other intangible assets:
Total	1,225	1,184
Accumulated amortization	(115)	(120)
Total other intangible assets subject to amortization - net	1,110	1,064
Intangible assets, amortization [Abstract]
Amortization expense	35	17	$ 15
Amortization Expense 2017	31
Amortization Expense 2018	46
Amortization Expense 2019	39
Amortization Expense 2020	26
Amortization Expense 2021	$ 19
Customer relationships associated with gas infrastructure
Other intangible assets:
Weighted average useful lives (years)	41 years
Total	$ 700	720
Purchased power agreements
Other intangible assets:
Weighted average useful lives (years)	22 years
Total	$ 444	328
Other, primarily transmission and development rights and customer lists
Other intangible assets:
Weighted average useful lives (years)	19 years
Total	$ 81	136
Gas Infrastructure, primarily Texas pipelines [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	641	635
Customer Supply [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	72	72
Generation Assets [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	38	43
Other Goodwill Assets [Member]
Goodwill and Intangible Assets [Line Items]
Goodwill	$ 28	$ 28

Employee Retirement Benefits -

Employee Retirement Benefits - Plan Assets, Benefit Obligations and Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Change in pension plan assets:
Plan assets, beginning balance	$ 3,563
Plan assets, ending balance	3,651	$ 3,563
Pension Benefits [Member]
Change in pension plan assets:
Plan assets, beginning balance	3,563	3,698
Actual return on plan assets	217	(8)
Benefit payments	(129)	(127)
Plan assets, ending balance	3,651	3,563	$ 3,698
Change in pension benefit obligation:
Obligation, beginning balance	2,408	2,454
Service cost	62	70	61
Interest cost	105	97	101
Plan amendments	(19)	0
Actuarial losses (gains) - net	47	(86)
Benefit payments	(129)	(127)
Obligation, ending balance	2,474	2,408	$ 2,454
Funded status:
Prepaid (accrued) benefit cost	1,177	1,155
Accumulated benefit obligation	2,439	2,366
Pension Benefits [Member] | FPL [Member]
Funded status:
Prepaid (accrued) benefit cost	$ 1,301	$ 1,243

Employee Retirement Benefits 46

Employee Retirement Benefits - Unrecognized Amounts (Details) - Pension Benefits [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Components of AOCI:
Unrecognized prior service benefit (cost) (net of $2 tax expense and $1 tax benefit, respectively)	$ 3	$ (2)
Unrecognized losses (net of $55 and $38 tax benefit, respectively)	(87)	(60)
Total	(84)	(62)
Tax effects on components of AOCI [Abstract]
Tax expense (benefit) related to unrecognized prior service benefit (cost)	2	(1)
Tax expense (benefit) related to unrecognized gain (loss)	(55)	(38)
Unrecognized amounts included in regulatory assets (liabilities) [Abstract]
Unrecognized prior service cost (benefit)	(4)	9
Unrecognized losses	280	232
Total	$ 276	$ 241
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.75%	7.75%	7.75%

Employee Retirement Benefits 47

Employee Retirement Benefits - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Target asset allocations [Abstract]
Defined contribution expense	$ 52	$ 63	$ 59
FPL [Member]
Target asset allocations [Abstract]
Defined contribution expense	32	40	$ 37
Other Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Funded Status of Plan	325	321
Other Benefits [Member] | FPL [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Funded Status of Plan	222	230
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Funded Status of Plan	$ 1,177	$ 1,155
Weighted-average assumptions used to determine benefit obligations [Abstract]
Discount rate (in hundredths)	4.09%	4.35%
Salary increase (in hundredths)	4.10%	4.10%
Pension Benefits [Member] | FPL [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Funded Status of Plan	$ 1,301	$ 1,243
Pension Benefits [Member] | Equity Securities [Member]
Target asset allocations [Abstract]
Equity investments, target allocation percentage (in hundredths)	45.00%
Pension Benefits [Member] | Debt Securities [Member]
Target asset allocations [Abstract]
Equity investments, target allocation percentage (in hundredths)	32.00%
Pension Benefits [Member] | Alternative Investments [Member]
Target asset allocations [Abstract]
Equity investments, target allocation percentage (in hundredths)	13.00%
Pension Benefits [Member] | Convertible Securities [Member]
Target asset allocations [Abstract]
Equity investments, target allocation percentage (in hundredths)	10.00%

Employee Retirement Benefits 48

Employee Retirement Benefits - Fair Value of Pension Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair value measurements of plan assets [Abstract]
Fair value	$ 3,651	$ 3,563
Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	2,592	2,589
Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	1,046	1,038
Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	1,542	1,549
Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	4	2
Equity Securities [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	370	384
Equity Securities [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	898	932
Equity Securities [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	879	910
Equity Securities [Member] | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	16	21
Equity Securities [Member] | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	3	1
Equity Commingled Vehicles [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	261	249
Equity Commingled Vehicles [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	845	792
Equity Commingled Vehicles [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Equity Commingled Vehicles [Member] | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	845	792
Equity Commingled Vehicles [Member] | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
U.S. Government And Municipal Bonds [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	155	123
U.S. Government And Municipal Bonds [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	143	110
U.S. Government And Municipal Bonds [Member] | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	12	13
U.S. Government And Municipal Bonds [Member] | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Corporate debt securities [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	67	68
Corporate debt securities [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	250	280
Corporate debt securities [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	3	2
Corporate debt securities [Member] | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	246	277
Corporate debt securities [Member] | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	1	1
Asset-backed securities [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	124	167
Asset-backed securities [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Asset-backed securities [Member] | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	124	167
Asset-backed securities [Member] | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Debt Security Commingled Vehicles [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	22	21
Debt Security Commingled Vehicles [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Debt Security Commingled Vehicles [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair value measurements of plan assets [Abstract]
Fair value	22	21
Debt Security Commingled Vehicles [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Convertible securities [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	31	23
Convertible securities [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	298	274
Convertible securities [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	21	16
Convertible securities [Member] | Significant Other Observable Inputs (Level 2) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	277	258
Convertible securities [Member] | Significant Unobservable Inputs (Level 3) [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	0	0
Investments measured at net asset value [Member]
Fair value measurements of plan assets [Abstract]
Foreign investments	282	283
Investments measured at net asset value [Member] | Reported Value Measurement [Member]
Fair value measurements of plan assets [Abstract]
Fair value	$ 1,059	$ 974

Employee Retirement Benefits 49

Employee Retirement Benefits - Expected Cash Flows (Details) - Pension Benefits [Member] $ in Millions	Dec. 31, 2016USD ($)
Defined Benefit Plan Disclosure [Line Items]
2,017	$ 155
2,018	156
2,019	160
2,020	163
2,021	170
2022 - 2026	$ 879

Employee Retirement Benefits 50

Employee Retirement Benefits - Net Periodic Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets, Net of Management Fees	7.35%	7.35%
Net periodic benefit (income) cost [Abstract]
Service cost	$ 62	$ 70	$ 61
Interest cost	105	97	101
Expected return on plan assets	(260)	(253)	(241)
Amortization of prior service cost (benefit)	1	1	5
Amortization of losses	0	0	0
Net periodic (income) cost	(92)	(85)	(74)
Other Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Service cost	2	3	3
Interest cost	13	13	16
Expected return on plan assets	(1)	(1)	(1)
Amortization of prior service cost (benefit)	(2)	(3)	(3)
Amortization of losses	0	2	0
Net periodic (income) cost	12	14	15
FPL [Member] | Pension Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Net periodic (income) cost	(58)	(55)	(47)
FPL [Member] | Other Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Net periodic (income) cost	$ 9	$ 11	$ 11

Employee Retirement Benefits 51

Employee Retirement Benefits - Net Periodic Income Cost Recognizedf for OCI (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Total	$ 21	$ 42	$ 43
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service benefit (net of $3 and $3 tax expense, respectively)	4	0	4
Net losses (net of $16, $27 and $29 tax benefit, respectively)	(26)	(44)	(45)
Amortization of prior service benefit	0	0	1
Total	(22)	(44)	(40)
Tax effects on components of net periodic income (cost) recognized in OCI [Abstract]
Prior service benefit (cost)	3	0	3
Net gains (losses)	$ (16)	$ (27)	$ (29)

Employee Retirement Benefits 52

Employee Retirement Benefits - Net Periodic Income Cost Regulatory Assets (Details) - Pension Benefits [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Prior service benefit	$ (12)	$ 0
Unrecognized losses	48	104
Amortization of prior service benefit	(1)	(1)
Total	$ 35	$ 103

Employee Retirement Benefits 53

Employee Retirement Benefits - Assumptions Used for Periodic Income (Details) - Pension Benefits [Member]	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.35%	3.95%	4.80%
Salary increase	4.10%	4.10%	4.00%
Expected long-term rate of return	7.75%	7.75%	7.75%
Expected long-term rate of return, net of management fees	7.35%	7.35%

Derivative Instruments (Details

Derivative Instruments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ (80)
Derivative, Collateral, Obligation to Return Cash	5	$ 27
Margin Cash Collateral Not Netted Against Derivative Liabilities	129	$ 116
Interest Expense [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Derivative [Line Items]
Reclassification from AOCI, Current Period, before Tax, Attributable to Parent	18
Reclassification from AOCI, Current Period, Net of Tax, Attributable to Parent	$ 11

Derivative Instruments (Balance

Derivative Instruments (Balance Sheet Disclosure) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets	$ 2,235	$ 1,971
Derivative Liabilities	881	1,428
Current derivative assets [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets	885	712
Margin cash collateral received from counterparties	96	279
Long Lived Assets Held-for-sale, Name [Domain]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets		57
Non Current Derivative Assets Member [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets	1,350	1,202
Margin cash collateral received from counterparties	71	151
Current derivative liabilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Liabilities	404	882
Margin cash collateral paid to counterparties		46
liabilities associated with assets held-for-sale [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Liabilities		16
Noncurrent derivative liabilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Liabilities	477	530
Margin cash collateral paid to counterparties		13
Interest Rate Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets		34
Derivative Liabilities		319
Foreign currency contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets		0
Derivative Liabilities		127
Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset		33
Derivative Liability, Fair Value, Gross Liability		287
Designated as Hedging Instrument [Member] | Commodity contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset		0
Derivative Liability, Fair Value, Gross Liability		0
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset		33
Derivative Liability, Fair Value, Gross Liability		155
Designated as Hedging Instrument [Member] | Foreign currency contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset		0
Derivative Liability, Fair Value, Gross Liability		132
Not Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset	4,879	5,908
Derivative Liability, Fair Value, Gross Liability	3,358	4,740
Derivative Assets	2,235
Derivative Liabilities	881
Not Designated as Hedging Instrument [Member] | Commodity contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset	4,590	5,906
Derivative Liability, Fair Value, Gross Liability	2,968	4,580
Derivative Assets	1,938	1,937
Derivative Liabilities	483	982
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset	288	2
Derivative Liability, Fair Value, Gross Liability	284	160
Derivative Assets	296
Derivative Liabilities	292
Not Designated as Hedging Instrument [Member] | Foreign currency contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset	1	0
Derivative Liability, Fair Value, Gross Liability	106	0
Derivative Assets	1
Derivative Liabilities	106
FPL [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets	209	4
Derivative Liabilities	1	222
FPL [Member] | Current derivative assets [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets	209	3
FPL [Member] | Current derivative liabilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Liabilities	1	222
FPL [Member] | Other Noncurrent Assets [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Assets		1
FPL [Member] | Commodity contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset
FPL [Member] | Designated as Hedging Instrument [Member] | Commodity contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset		0
Derivative Liability, Fair Value, Gross Liability		0
FPL [Member] | Not Designated as Hedging Instrument [Member] | Commodity contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Abstract]
Derivative Asset, Fair Value, Gross Asset	212	7
Derivative Liability, Fair Value, Gross Liability	4	225
Derivative Assets	209	4
Derivative Liabilities	$ 1	$ 222

Derivative Instruments (Income

Derivative Instruments (Income Statement Disclosure) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	$ 551	$ 948	$ 356
Gains (losses) on commodity contracts, recorded as regulatory assets and or liabilities on the balance sheet due to regulatory treatment	203	(326)	(289)
Cash Flow Hedging [Member]
Gains (losses) related to cash flow hedges [Abstract]
Losses recognized in OCI		(125)	(221)
Losses reclassified from AOCI to net income		(88)	(155)
Foreign currency contracts [Member] | Cash Flow Hedging [Member]
Gains (losses) related to cash flow hedges [Abstract]
Losses recognized in OCI		(12)	(89)
Losses reclassified from AOCI to net income		(15)	(78)
Foreign currency contracts [Member] | Gain (loss) included in interest expense [Member]
Gains (losses) related to cash flow hedges [Abstract]
Losses reclassified from AOCI to net income		(11)	(8)
Interest Rate Contract [Member] | Cash Flow Hedging [Member]
Gains (losses) related to cash flow hedges [Abstract]
Losses recognized in OCI		(113)	(132)
Losses reclassified from AOCI to net income		(73)	(77)
Not Designated as Hedging Instrument [Member] | Commodity contracts [Member] | Gains (Losses) Included In Operating Revenues [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	459	932	420
Not Designated as Hedging Instrument [Member] | Commodity contracts [Member] | Gains (Losses) Included In Fuel, Purchased Power And Interchange [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	(1)	8	1
Not Designated as Hedging Instrument [Member] | Foreign currency contracts [Member] | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	14	0	0
Not Designated as Hedging Instrument [Member] | Foreign currency contracts [Member] | Gains (Losses) Included In Other - Net [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	(1)	0	(1)
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Gains (losses) related to derivatives not designated as hedging instruments	181	8	(64)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Not Designated as Hedging Instrument [Member] | Foreign currency contracts [Member] | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Interest Expense	(11)	0	0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Gain (loss) included in interest expense [Member]
Gains (losses) related to derivatives not designated as hedging instruments [Abstract]
Interest Expense	$ (90)	$ 0	$ 0

Derivative Instruments (Net Not

Derivative Instruments (Net Notional Volumes and Additional Disclosures) (Details) bbl in Millions, MWh in Millions, MMBTU in Millions, $ in Millions	Dec. 31, 2016USD ($)MWhMMBTUbbl	Dec. 31, 2015USD ($)MWhMMBTUbbl
Derivative [Line Items]
Collateral Already Posted, Aggregate Fair Value	$ 1	$ 0
Commodity contract - Power [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Non monetary net notional volumes | MWh	84	112
Commodity contract - Natural gas [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Non monetary net notional volumes | MMBTU	1,002	1,321
Commodity contract - Oil [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Non monetary net notional volumes | bbl	7	9
Interest Rate Swap [Member]
Derivative [Line Items]
Notional Amount of Foreign Currency Cash Flow Hedge Derivatives	$ 15,100	$ 8,300
Currency Swap [Member]
Derivative [Line Items]
Notional Amount of Foreign Currency Cash Flow Hedge Derivatives	705	715
FPL [Member]
Derivative [Line Items]
Collateral Already Posted, Aggregate Fair Value	$ 0	$ 0
FPL [Member] | Commodity contract - Power [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Non monetary net notional volumes | MWh	0	0
FPL [Member] | Commodity contract - Natural gas [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Non monetary net notional volumes | MMBTU	618	833
FPL [Member] | Commodity contract - Oil [Member]
Schedule of net notional volume of commodity derivative instruments [Abstract]
Non monetary net notional volumes | bbl	0	0

Derivative Instruments (Credit

Derivative Instruments (Credit Risk Disclosures) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Derivative [Line Items]
Liability position of derivative	$ 1,300	$ 2,200
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Bbb Or Baa2	110	165
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Below Investment Grade	990	1,400
Additional Collateral Aggregate Fair Value Due To Other Financial Measures	225	270
Collateral Already Posted, Aggregate Fair Value	1	0
Letters Of Credit Already Posted Aggregate Fair Value	30	123
FPL [Member]
Derivative [Line Items]
Liability position of derivative	5	224
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Bbb Or Baa2	0	20
Additional Collateral Aggregate Fair Value Due To Credit Rating Downgrade To Below Investment Grade	10	185
Additional Collateral Aggregate Fair Value Due To Other Financial Measures	115	120
Collateral Already Posted, Aggregate Fair Value	0	0
Letters Of Credit Already Posted Aggregate Fair Value	$ 0	$ 3

Fair Value Measurements (Assets

Fair Value Measurements (Assets and Liabilities Measured on a Recurring Basis) (Details) - Fair Value, Measurements, Recurring [Member] - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	$ 982	$ 312
Special use funds [Abstract]
Equity securities	2,913	2,674
U.S. Government and municipal bonds	466	612
Corporate debt securities	764	713
Mortgage-backed securities	498	412
Other debt securities	81	52
Other Investments [Abstract]
Equity securities	35	40
Debt securities	161	171
Derivatives [Abstract]
Commodity contracts	1,938	1,937
Interest rate contracts	296	34
Foreign currency contracts	1
Derivatives [Abstract]
Commodity contracts	483	982
Interest rate contracts	292	319
Foreign currency contracts	106	127
Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	982	312
Special use funds [Abstract]
Equity securities	1,410	1,320
U.S. Government and municipal bonds	296	446
Corporate debt securities	1	0
Mortgage-backed securities	0	0
Other debt securities	0	0
Other Investments [Abstract]
Equity securities	26	30
Debt securities	8	39
Derivatives [Abstract]
Commodity contracts	1,563	2,187
Interest rate contracts	0	0
Foreign currency contracts	0
Derivatives [Abstract]
Commodity contracts	1,476	2,153
Interest rate contracts	0	0
Foreign currency contracts	0	0
Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Current other assets [Member]
Assets [Abstract]
Restricted cash	164	61
Fair Value, Inputs, Level 2 [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	0	0
Special use funds [Abstract]
Equity securities	1,503	1,354
U.S. Government and municipal bonds	170	166
Corporate debt securities	763	713
Mortgage-backed securities	498	412
Other debt securities	81	52
Other Investments [Abstract]
Equity securities	9	10
Debt securities	153	132
Derivatives [Abstract]
Commodity contracts	1,827	2,540
Interest rate contracts	285	35
Foreign currency contracts	1
Derivatives [Abstract]
Commodity contracts	980	1,887
Interest rate contracts	171	214
Foreign currency contracts	106	132
Significant Unobservable Inputs (Level 3) [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	0	0
Special use funds [Abstract]
Equity securities	0	0
U.S. Government and municipal bonds	0	0
Corporate debt securities	0	0
Mortgage-backed securities	0	0
Other debt securities	0	0
Other Investments [Abstract]
Equity securities	0	0
Debt securities	0	0
Derivatives [Abstract]
Commodity contracts	1,200	1,179
Interest rate contracts	3	0
Foreign currency contracts	0
Derivatives [Abstract]
Commodity contracts	512	540
Interest rate contracts	113	101
Foreign currency contracts	0	0
FPL [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	120	36
Special use funds [Abstract]
Equity securities	1,745	1,598
U.S. Government and municipal bonds	362	480
Corporate debt securities	547	531
Mortgage-backed securities	384	327
Other debt securities	70	40
Derivatives [Abstract]
Commodity contracts	209	4
Derivatives [Abstract]
Commodity contracts	1	222
FPL [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	120	36
Special use funds [Abstract]
Equity securities	373	364
U.S. Government and municipal bonds	221	335
Corporate debt securities	0	0
Mortgage-backed securities	0	0
Other debt securities	0	0
Derivatives [Abstract]
Commodity contracts	0	0
Derivatives [Abstract]
Commodity contracts	0	0
FPL [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Current other assets [Member]
Assets [Abstract]
Restricted cash	120	36
FPL [Member] | Fair Value, Inputs, Level 2 [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	0	0
Special use funds [Abstract]
Equity securities	1,372	1,234
U.S. Government and municipal bonds	141	145
Corporate debt securities	547	531
Mortgage-backed securities	384	327
Other debt securities	70	40
Derivatives [Abstract]
Commodity contracts	208	1
Derivatives [Abstract]
Commodity contracts	1	219
FPL [Member] | Significant Unobservable Inputs (Level 3) [Member]
Assets [Abstract]
Cash equivalents and restricted cash - equity securities	0	0
Special use funds [Abstract]
Equity securities	0	0
U.S. Government and municipal bonds	0	0
Corporate debt securities	0	0
Mortgage-backed securities	0	0
Other debt securities	0	0
Derivatives [Abstract]
Commodity contracts	4	6
Derivatives [Abstract]
Commodity contracts	3	6
Commodity contracts [Member]
Derivatives [Abstract]
Asset offsetting	(2,652)	(3,969)
Derivatives [Abstract]
Liability offsetting	(2,485)	3,598
Commodity contracts [Member] | FPL [Member]
Derivatives [Abstract]
Asset offsetting	(3)	(3)
Derivatives [Abstract]
Liability offsetting	(3)	3
Interest Rate Contract [Member]
Derivatives [Abstract]
Asset offsetting	8	(1)
Derivatives [Abstract]
Liability offsetting	8	4
Currency Swap [Member]
Derivatives [Abstract]
Asset offsetting	0
Derivatives [Abstract]
Liability offsetting	$ 0	$ 5

Fair Value Measurements (Signif

Fair Value Measurements (Significant Unobservable Inputs) (Details) - Significant Unobservable Inputs (Level 3) [Member] $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)$ / MMBTU$ / MWh$ / energy_unit
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	$ 1,200
Liabilities, Fair Value Disclosure	512
Forward Contracts - Power [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	621
Liabilities, Fair Value Disclosure	$ 206
Forward Contracts - Power [Member] | Forward Price [Member] | Maximum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit | $ / MWh	91
Forward Contracts - Power [Member] | Forward Price [Member] | Minimum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit | $ / MWh	0
Forward contracts - Gas [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	$ 27
Liabilities, Fair Value Disclosure	$ 10
Forward contracts - Gas [Member] | Forward Price [Member] | Maximum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit | $ / MMBTU	11
Forward contracts - Gas [Member] | Forward Price [Member] | Minimum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit | $ / MMBTU	2
Forward contracts - Other [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	$ 7
Liabilities, Fair Value Disclosure	$ 1
Forward contracts - Other [Member] | Forward Price [Member] | Maximum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit | $ / energy_unit	57
Forward contracts - Other [Member] | Forward Price [Member] | Minimum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit | $ / energy_unit	(17)
Option Contracts, Power [Member] | Options Models, Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	$ 43
Liabilities, Fair Value Disclosure	$ 10
Option Contracts, Power [Member] | Implied Correlations [Member] | Maximum [Member] | Options Models, Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Expected Rates	100.00%
Option Contracts, Power [Member] | Implied Correlations [Member] | Minimum [Member] | Options Models, Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Expected Rates	1.00%
Option Contracts, Power [Member] | Implied Volatilities [Member] | Maximum [Member] | Options Models, Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Expected Rates	296.00%
Option Contracts, Power [Member] | Implied Volatilities [Member] | Minimum [Member] | Options Models, Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Expected Rates	9.00%
Options - primarily gas [Member] | Options Models, Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	$ 223
Liabilities, Fair Value Disclosure	$ 230
Options - primarily gas [Member] | Implied Correlations [Member] | Maximum [Member] | Options Models, Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Expected Rates	100.00%
Options - primarily gas [Member] | Implied Correlations [Member] | Minimum [Member] | Options Models, Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Expected Rates	1.00%
Options - primarily gas [Member] | Implied Volatilities [Member] | Maximum [Member] | Options Models, Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Expected Rates	260.00%
Options - primarily gas [Member] | Implied Volatilities [Member] | Minimum [Member] | Options Models, Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Expected Rates	1.00%
Full Requirements and Unit Contingent Contracts [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	$ 279
Liabilities, Fair Value Disclosure	$ 55
Full Requirements and Unit Contingent Contracts [Member] | Forward Price [Member] | Maximum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit | $ / MWh	220
Full Requirements and Unit Contingent Contracts [Member] | Forward Price [Member] | Minimum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Offered Quotes, Price Per Energy Unit | $ / MWh	(20)
Full Requirements and Unit Contingent Contracts [Member] | Customer Migration Rate [Member] | Maximum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Expected Rates	20.00%
Full Requirements and Unit Contingent Contracts [Member] | Customer Migration Rate [Member] | Minimum [Member] | Discounted Cash Flow Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Inputs, Expected Rates	0.00%
NEER [Member] | Interest Rate Swap [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Liabilities, Fair Value Disclosure	$ 110

Fair Value Measurements (Reconc

Fair Value Measurements (Reconciliation of Change in Fair Value of Derivatives, Significant Unobservable Inputs) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Realized and unrealized gains (losses):
Realized and unrealized gains (losses) reflected in operating revenues	$ 397	$ 462
Realized and unrealized gains (losses) reflected in interest expense			$ (79)
Unrealized gains (losses) reflected in operating revenues, for derivatives still held at the reporting date	283	289	328
Derivative Financial Instruments, Net [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair value of derivatives based on significant unobservable inputs beginning balance	538	622	622
Realized and unrealized gains (losses):
Realized and unrealized gains (losses) included in earnings	333	451	(77)
Realized and unrealized gains (losses) included in other comprehensive income (loss)	8	11	18
Realized and unrealized gains (losses) included in regulatory assets and liabilities	1	3	7
Purchases	261	180	55
Settlements	(390)	(473)	194
Issuances	(195)	(202)	(122)
Transfers in(b)	19	(13)	80
Transfers out(b)	3	(41)	(155)
Fair value of derivatives based on significant unobservable inputs ending balance	578	538	622
The amount of gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to derivatives still held at the reporting date(c)	219	277	248
FPL [Member] | Derivative Financial Instruments, Net [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair value of derivatives based on significant unobservable inputs beginning balance	0	5	0
Realized and unrealized gains (losses):
Realized and unrealized gains (losses) included in earnings	0	0	0
Realized and unrealized gains (losses) included in other comprehensive income (loss)	0	0	0
Realized and unrealized gains (losses) included in regulatory assets and liabilities	1	3	7
Purchases	0	0	0
Settlements	0	(8)	(2)
Issuances	0	0	0
Transfers in(b)	0	0	0
Transfers out(b)	0	0	0
Fair value of derivatives based on significant unobservable inputs ending balance	1	0	5
The amount of gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to derivatives still held at the reporting date(c)	$ 0	$ 0	$ 0

Fair Value Measurements (Nonrec

Fair Value Measurements (Nonrecurring Fair Value Measurements) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gain associated with Maine fossil	$ 0	$ 0	$ 21
Maine fossil [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gain associated with Maine fossil		21
After-tax gain (loss) on assets previously held for sale		$ 12

Fair Value Measurements (Fair V

Fair Value Measurements (Fair Value of Instruments Recorded at Other than Fair Value) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Storm Fund Assets	$ 0	$ 74
Decommissioning Fund Investments, Fair Value	5,434	5,064
Available for sale debt securities amortized cost	1,820	1,823
Available-for-sale equity securities, amortized cost	$ 1,543	1,505
Special Use Funds Nuclear Decommissioning Funds Weighted Average Maturity	9 years
FPL [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term Debt	$ 10,072	10,020
Decommissioning Fund Investments, Fair Value	3,665	3,430
Available for sale debt securities amortized cost	1,373	1,409
Available-for-sale equity securities, amortized cost	$ 764	732
Special Use Funds Nuclear Decommissioning Funds Weighted Average Maturity	9 years
Reported Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	$ 712	675
Other Investments Primarily Notes Receivable Fair Value Disclosure	526	512
Long Term Debt Including Current Maturities Fair Value Disclosure	30,418	28,897
Reported Value Measurement [Member] | FPL [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	557	528
Long Term Debt Including Current Maturities Fair Value Disclosure	10,072	10,020
Estimate of Fair Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	712	675
Other Investments Primarily Notes Receivable Fair Value Disclosure	668	722
Long Term Debt Including Current Maturities Fair Value Disclosure	31,623	30,412
Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long Term Debt Including Current Maturities Fair Value Disclosure	29,804	18,031
Estimate of Fair Value Measurement [Member] | FPL [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Fair Value Disclosure	557	528
Long Term Debt Including Current Maturities Fair Value Disclosure	11,211	11,028
liabilities associated with assets held-for-sale [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term Debt	$ 373	$ 938

Fair Value Measurements (Availa

Fair Value Measurements (Available for Sale Securities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Available-for-sale Securities[Line Items]
Realized gains	$ 116	$ 194	$ 211
Realized losses	76	87	115
Proceeds from sale and maturity of Available-for-sale Securities	3,400	4,643	4,092
FPL [Member]
Schedule of Available-for-sale Securities[Line Items]
Realized gains	53	70	120
Realized losses	44	43	94
Proceeds from sale and maturity of Available-for-sale Securities	2,442	3,724	$ 3,349
Available For Sale Securities: Special Use Funds - Equity Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
Unrealized gains	1,396	1,166
Available For Sale Securities: Special Use Funds - Equity Securities [Member] | FPL [Member]
Schedule of Available-for-sale Securities[Line Items]
Unrealized gains	1,007	863
Available for sale securities: Special Use Funds - Debt Securities [Member]
Schedule of Available-for-sale Securities[Line Items]
Unrealized gains	22	17
Unrealized losses	34	51
Fair Value	959	1,129
Available for sale securities: Special Use Funds - Debt Securities [Member] | FPL [Member]
Schedule of Available-for-sale Securities[Line Items]
Unrealized gains	17	14
Unrealized losses	28	45
Fair Value	$ 722	$ 861

Income Taxes - Components of In

Income Taxes - Components of Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Federal:
Current	$ 72	$ 10	$ 0
Deferred	1,075	1,194	1,077
Total federal	1,147	1,204	1,077
State:
Current	76	31	(29)
Deferred	160	(7)	128
Total state	236	24	99
Total income taxes	1,383	1,228	1,176
FPL [Member]
Federal:
Current	72	423	240
Deferred	830	399	542
Total federal	902	822	782
State:
Current	57	58	68
Deferred	92	77	60
Total state	149	135	128
Total income taxes	$ 1,051	$ 957	$ 910

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating Loss Carryforwards [Line Items]
Statutory federal income tax rate (in hundredths)	35.00%	35.00%	35.00%
Increases (reductions) resulting from:
State income taxes - net of federal income tax benefit (in hundredths)	3.50%	0.40%	1.80%
PTCs and ITCs - NEER (in hundredths)	(3.90%)	(4.10%)	(5.10%)
Convertible ITCs - NEER (in hundredths)	(1.70%)	(0.80%)	(1.40%)
Adjustments associated with Canadian assets (in hundredths)	(0.70%)	0.00%	1.30%
Other - net (in hundredths)	(0.70%)	0.30%	0.70%
Effective income tax rate (in hundredths)	31.50%	30.80%	32.30%
FPL [Member]
Operating Loss Carryforwards [Line Items]
Statutory federal income tax rate (in hundredths)	35.00%	35.00%	35.00%
Increases (reductions) resulting from:
State income taxes - net of federal income tax benefit (in hundredths)	3.50%	3.40%	3.40%
PTCs and ITCs - NEER (in hundredths)	0.00%	0.00%	0.00%
Convertible ITCs - NEER (in hundredths)	0.00%	0.00%	0.00%
Adjustments associated with Canadian assets (in hundredths)	0.00%	0.00%	0.00%
Other - net (in hundredths)	(0.70%)	(1.70%)	(0.90%)
Effective income tax rate (in hundredths)	37.80%	36.70%	37.50%

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Deferred tax liabilities:
Property-related	$ 13,094	$ 12,204
Pension	454	455
Nuclear decommissioning trusts	253	219
Net unrealized gains on derivatives	581	528
Investments in partnerships and joint ventures	603	403
Other	1,272	1,196
Total deferred tax liabilities	16,257	15,005
Deferred tax assets and valuation allowance:
Decommissioning reserves	454	438
Postretirement benefits	145	141
Net operating loss carryforwards	427	604
Tax credit carryforwards	3,059	2,916
ARO and accrued asset removal costs	777	759
Other	1,024	836
Valuation allowance(a)	(269)	(223)
Net deferred tax assets	5,617	5,471
Net deferred income taxes	10,640	9,534
Deferred tax assets and liabilities included in the consolidated balance sheets [Abstract]
Noncurrent other assets	461	293
Deferred income taxes - noncurrent liabilities	(11,101)	(9,827)
Net deferred income taxes	(10,640)	(9,534)
FPL [Member]
Deferred tax liabilities:
Property-related	8,882	8,040
Pension	502	480
Nuclear decommissioning trusts	0	0
Net unrealized gains on derivatives	0	0
Investments in partnerships and joint ventures	0	0
Other	796	695
Total deferred tax liabilities	10,180	9,215
Deferred tax assets and valuation allowance:
Decommissioning reserves	401	386
Postretirement benefits	93	95
Net operating loss carryforwards	3	4
Tax credit carryforwards	0	0
ARO and accrued asset removal costs	699	697
Other	443	303
Valuation allowance(a)	0	0
Net deferred tax assets	1,639	1,485
Net deferred income taxes	8,541	7,730
Deferred tax assets and liabilities included in the consolidated balance sheets [Abstract]
Noncurrent other assets	0	0
Deferred income taxes - noncurrent liabilities	(8,541)	(7,730)
Net deferred income taxes	$ (8,541)	$ (7,730)

Income Taxes - Tax Carryforward

Income Taxes - Tax Carryforwards and Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	$ 427	$ 604
Tax credit carryforwards	3,059	$ 2,916
Federal [Member]
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	165
Tax credit carryforwards	2,697
State [Member]
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	174
Tax credit carryforwards	362
Tax credit carryforward with indefinite expiration period	188
Foreign [Member]
Operating Loss and Tax Credit Carryforwards [Line Items]
Net operating loss carryforwards	88
Operating loss carryforwards with indefinite expiration period	$ 60

Jointly-Owned Electric Plants69

Jointly-Owned Electric Plants (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
FPL [Member] | Jointly Owned Nuclear Power Plant 1 [Member]
Proportionate ownership interest In jointly-owned facilities [Abstract]
Facility Name	St. Lucie Unit No. 2
Ownership Interest (in hundredths)	85.00%
Gross Investment	$ 2,172
Accumulated Depreciation	815
Construction Work in Progress	$ 33
FPL [Member] | Jointly Owned Nuclear Power Plant 2 [Member]
Proportionate ownership interest In jointly-owned facilities [Abstract]
Facility Name	St. Johns River Power Park units and coal terminal
Ownership Interest (in hundredths)	20.00%
Gross Investment	$ 393
Accumulated Depreciation	208
Construction Work in Progress	$ 0
FPL [Member] | Jointly Owned Nuclear Power Plant 3 [Member]
Proportionate ownership interest In jointly-owned facilities [Abstract]
Facility Name	Scherer Unit No. 4
Ownership Interest (in hundredths)	76.00%
Gross Investment	$ 1,138
Accumulated Depreciation	395
Construction Work in Progress	$ 3
NEER [Member] | Jointly Owned Electricity Generation Plant 1 [Member]
Proportionate ownership interest In jointly-owned facilities [Abstract]
Facility Name	Duane Arnold
Ownership Interest (in hundredths)	70.00%
Gross Investment	$ 466
Accumulated Depreciation	146
Construction Work in Progress	$ 16
NEER [Member] | Jointly Owned Electricity Generation Plant 2 [Member]
Proportionate ownership interest In jointly-owned facilities [Abstract]
Facility Name	Seabrook
Ownership Interest (in hundredths)	88.23%
Gross Investment	$ 1,138
Accumulated Depreciation	271
Construction Work in Progress	$ 77
NEER [Member] | Jointly Owned Electricity Generation Plant 3 [Member]
Proportionate ownership interest In jointly-owned facilities [Abstract]
Facility Name	Wyman Station Unit No. 4
Ownership Interest (in hundredths)	84.35%
Gross Investment	$ 25
Accumulated Depreciation	3
Construction Work in Progress	$ 0
Corporate and Other [Member] | Jointly Owned Electricity Transmission and Distribution System [Member]
Proportionate ownership interest In jointly-owned facilities [Abstract]
Facility Name	Transmission substation assets located in Seabrook, New Hampshire
Ownership Interest (in hundredths)	88.23%
Gross Investment	$ 76
Accumulated Depreciation	17
Construction Work in Progress	$ 3

Business Acquisitions (Details)

Business Acquisitions (Details) - USD ($) $ in Millions	Oct. 30, 2016	Oct. 29, 2016	Oct. 01, 2015	Sep. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Jun. 30, 2017	Jul. 29, 2016
Business Acquisition [Line Items]
Acquisitions related costs					$ 135	$ 26	$ 0
NET Holdings Management, LLC [Member]
Business Acquisition [Line Items]
Debt assumed			$ 706
Subsidiary of NextEra Energy Partners [Member] | NET Holdings Management, LLC [Member]
Business Acquisition [Line Items]
Membership interests acquired			100.00%
Noncontrolling interest ownership percentage			10.00%
Aggregate purchase price			$ 2,000
Cash consideration			934
Debt assumed			706
Working capital adjustments			2
Goodwill expected to be deductible			$ 380
Period goodwill is expected to be deductible (in years)			15 years
NextEra Energy Partners [Member] | NET Holdings Management, LLC [Member]
Business Acquisition [Line Items]
Acquisitions related costs						$ 13
EFH Merger Co., LLC, Wholly Owned Subsidiary of NEE [Member] | Energy Future Holdings Corp. [Member]
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests to be Acquired in Pending Merger									100.00%
EFH Merger Co., LLC, Wholly Owned Subsidiary of NEE [Member] | Oncor Electric Delivery Company LLC [Member]
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests to be Acquired in Pending Merger									80.03%
EFH Merger Co., LLC, Wholly Owned Subsidiary of NEE [Member] | Energy Future Holdings Corp and Certain Direct and Indirect Subsidiaries [Member]
Business Acquisition [Line Items]
Business Combination, Consideration To Be Transferred in Pending Merger				$ 9,796
WSS Acquisition Company, Wholly Owned Subsidiary of NEE [Member] | Oncor Electric Delivery Company LLC [Member]
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests to be Acquired in Pending Merger	20.00%
WSS Acquisition Company, Wholly Owned Subsidiary of NEE [Member] | Texas Transmission Holdings Corporation [Member]
Business Acquisition [Line Items]
Business Combination, Consideration To Be Transferred in Pending Merger	$ 2,410
Contingent Holdback [Member] | Subsidiary of NextEra Energy Partners [Member] | NET Holdings Management, LLC [Member]
Business Acquisition [Line Items]
Contingent consideration liability			$ 200
Indemnity Holdback [Member] | Subsidiary of NextEra Energy Partners [Member] | NET Holdings Management, LLC [Member]
Business Acquisition [Line Items]
Contingent consideration liability			200
Noncurrent other liabilities [Member] | Contingent Holdback [Member] | Subsidiary of NextEra Energy Partners [Member] | NET Holdings Management, LLC [Member]
Business Acquisition [Line Items]
Contingent consideration liability			186
Noncurrent other liabilities [Member] | Indemnity Holdback [Member] | Subsidiary of NextEra Energy Partners [Member] | NET Holdings Management, LLC [Member]
Business Acquisition [Line Items]
Contingent consideration liability			$ 186
Other Current Liabilities [Member] | Contingent Holdback [Member] | Subsidiary of NextEra Energy Partners [Member] | NET Holdings Management, LLC [Member]
Business Acquisition [Line Items]
Contingent consideration liability					0
Other Current Liabilities [Member] | Indemnity Holdback [Member] | Subsidiary of NextEra Energy Partners [Member] | NET Holdings Management, LLC [Member]
Business Acquisition [Line Items]
Contingent consideration liability					$ 199
Forecast [Member] | Oncor Electric Delivery Company LLC [Member]
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests to be Acquired in Pending Merger								100.00%
Oncor Management Investment LLC (OMI) [Member] | T & D Equity Acquisition, LLC, Wholly Owned Subsidiary of NEE [Member] | Oncor Electric Delivery Company LLC [Member]
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests to be Acquired in Pending Merger		0.22%
Business Combination, Consideration To Be Transferred in Pending Merger		$ 27

Business Acquisitions - Assets

Business Acquisitions - Assets Acquired and Liabilities Assumed (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Oct. 01, 2015
Assets:
Noncurrent other assets (goodwill, see Note 1 - Goodwill and Other Intangible Assets)	$ 779	$ 778
NET Holdings Management, LLC [Member]
Assets:
Property, plant and equipment			$ 806
Cash			1
Other receivables and current other assets			21
Noncurrent other assets (other intangible assets, see Note 1 - Goodwill and Other Intangible Assets)			720
Noncurrent other assets (goodwill, see Note 1 - Goodwill and Other Intangible Assets)			622
Total assets			2,170
Liabilities:
Long-term debt, including current portion			706
Accounts payable and current other liabilities			46
Noncurrent other liabilities, primarily acquisition holdbacks			415
Total liabilities			1,167
Less noncontrolling interest at fair value			69
Total cash consideration			$ 934

Variable Interest Entities (Det

Variable Interest Entities (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)entitiesvariable_interest_entityMW	Dec. 31, 2015USD ($)entities	Dec. 31, 2014USD ($)	Jul. 01, 2014	Dec. 31, 2007USD ($)
Variable Interest Entity [Line Items]
Total number of consolidated variable interest entities (in entities)	33
Investment in equity method investees	$ 1,767	$ 1,063	$ 663
NEP OpCo [Member]
Variable Interest Entity [Line Items]
Total number of consolidated variable interest entities (in entities) | variable_interest_entity	1
Carrying amount of assets, consolidated variable interest entity	$ 7,200
Carrying amount of liabilities, consolidated variable interest entity	5,000
Other variable interest entities [Member]
Variable Interest Entity [Line Items]
Investments in special purpose entities	2,505	602
FPL [Member] | Bankruptcy remote special purpose subsidiary [Member]
Variable Interest Entity [Line Items]
Storm-recovery bonds aggregate principal amount issued					$ 652
Proceeds from issuance of storm-recovery bonds					$ 644
Carrying amount of assets, consolidated variable interest entity	216	230
Carrying amount of liabilities, consolidated variable interest entity	$ 214	278
FPL [Member] | Qualifying facility 2 [Member]
Variable Interest Entity [Line Items]
Coal fired generating facility capacity (in megawatts) | MW	330
FPL [Member] | Other variable interest entities [Member]
Variable Interest Entity [Line Items]
Investments in special purpose entities	$ 2,049	476
NEER [Member]
Variable Interest Entity [Line Items]
Total number of consolidated variable interest entities (in entities) | entities	32
Investment in equity method investees	$ 1,488	871
NEER [Member] | Gas and/or oil variable interest entities [Member]
Variable Interest Entity [Line Items]
Carrying amount of assets, consolidated variable interest entity	95	84
Carrying amount of liabilities, consolidated variable interest entity	$ 42	$ 47
Natural gas and or oil electric generating facility capacity (in megawatts) | MW	110
NEER [Member] | Photovoltaic Solar Facility [Member]
Variable Interest Entity [Line Items]
Solar Generating Facility Capability | MW	374
NEER [Member] | Special Purpose Entity that has Insufficient Equity at Risk [Member]
Variable Interest Entity [Line Items]
Total number of consolidated variable interest entities (in entities) | variable_interest_entity	1
Carrying amount of assets, consolidated variable interest entity	$ 502
Carrying amount of liabilities, consolidated variable interest entity	$ 511
NEER [Member] | Wind variable interest entities [Member]
Variable Interest Entity [Line Items]
Total number of consolidated variable interest entities (in entities) | entities	27	20
Carrying amount of assets, consolidated variable interest entity	$ 10,900	$ 7,600
Carrying amount of liabilities, consolidated variable interest entity	$ 6,900	5,000
Wind electric generating facility capability (in megawatts) | MW	6,847
NEER [Member] | Gas and or Oil Variable Interest Entities [Member]
Variable Interest Entity [Line Items]
Total number of consolidated variable interest entities (in entities) | entities	1
Indirect Subsidiary of NextEra Energy Resources [Member] | Photovoltaic Solar Facility [Member]
Variable Interest Entity [Line Items]
Total number of consolidated variable interest entities (in entities) | entities	2
Carrying amount of assets, consolidated variable interest entity	$ 571	657
Carrying amount of liabilities, consolidated variable interest entity	$ 487	$ 626
Ownership percentage (in hundredths)	50.00%
Solar Generating Facility Capability | MW	277
Subsidiaries of NEE [Member]
Variable Interest Entity [Line Items]
Equity Method Investments, Additional Commitments to Invest	$ 30
Equity Method Investments, Additional Variable Interest Entities Committed to Invest In | variable_interest_entity	2
NEP OpCo [Member]
Variable Interest Entity [Line Items]
Noncontrolling interest ownership percentage	65.20%			79.90%
Other Investments [Member]
Variable Interest Entity [Line Items]
Investment in equity method investees	$ 234

Investments in Partnerships a73

Investments in Partnerships and Joint Ventures (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2004	Dec. 31, 2014
Equity method investment, financial statement, reported amounts [Abstract]
Ownership interest in partnerships and joint ventures	$ 1,767	$ 1,063
NextEra Energy Resources' ownership interest, low range (in hundredths)	31.00%
NextEra Energy Resources' ownership interest, high range (in hundredths)	50.00%
Preferred trust securities [Abstract]
Proceeds from sale of preferred trust securities to the public			$ 300
Proceeds from sale of common trust securities to NextEra Energy			$ 9
Ownership interest in trust (in hundredths)			100.00%
Interest rate of junior subordinated debentures (in hundredths)			5.875%
Equity method investment, summarized financial information [Abstract]
Net income	$ 264	213
Total assets	4,502	3,339
Total liabilities	1,364	1,307
Partners'/members' equity	3,138	2,032
NEER's investment carrying amount for the principal entities	1,767	1,063		$ 663
NEER [Member]
Equity method investment, summarized financial information [Abstract]
NEER's share of underlying equity in the principal entities	1,423	874
Difference between investment carrying amount and underlying equity in net assets	65	(3)
NEER's investment carrying amount for the principal entities	$ 1,488	$ 871

Common Shareholders' Equity (Ea

Common Shareholders' Equity (Earnings Per Share) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Reconciliation of basic and diluted earnings per share of common stock [Abstract]
Net income (loss) attributable to parent	$ 966	$ 753	$ 540	$ 653	$ 507	$ 879	$ 716	$ 650	$ 2,912	$ 2,752	$ 2,465
Denominator:
Weighted-average number of common shares outstanding - basic									463.1	450.5	434.4
Equity units, performance share awards, stock options, forward sale agreement and restricted stock(a)									2.7	3.5	5.7
Weighted-average number of common shares outstanding - assuming dilution									465.8	454	440.1
Earnings per share attributable to NEE from continuing operations:
Basic EPS (in dollars per share)									$ 6.29	$ 6.11	$ 5.67
Diluted EPS (in dollars per share)									$ 6.25	$ 6.06	$ 5.60
Antidilutive securities (in shares)									7.9	3.5	2.6

Common Shareholders' Equity (Is

Common Shareholders' Equity (Issuance of Common Stock and Forward Sale Agreement) (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	12 Months Ended
	Nov. 30, 2013	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Jan. 01, 2016
Class of Stock [Line Items]
Stock sold during the period	4,500,000
Share Price (in dollars per share)	$ 88.03
Forward sale price (in dollars per share)		$ 124
Settlement of shares		12,000,000
Proceeds from forward sale agreement		$ 1,500
Antidilutive securities (in shares)		7,900,000	3,500,000	2,600,000
Forward Counterparty [Member]
Class of Stock [Line Items]
Stock sold during the period	6,600,000
Shares delivered				6,600,000
Proceeds from Equity				$ 552
Adjustments for New Accounting Principle, Early Adoption [Member]
Class of Stock [Line Items]
Unrecognized Tax Benefits					$ (18)
Excess tax benefits		$ 30
Forward Contracts [Member]
Class of Stock [Line Items]
Antidilutive securities (in shares)		12,000,000

Common Shareholders' Equity (St

Common Shareholders' Equity (Stock-Based Compensation) (Details) - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Stock-based compensation
Stock based compensation costs	$ 77	$ 60	$ 60
Tax benefits related to stock-based compensation arrangements	30	$ 23	$ 23
Unrecognized stock based compensation costs	$ 78
Unrecognized stock based compensation costs weighted-average period of recognition (in years)	1 year 9 months
Common stock authorized for awards (in shares)	16

Common Shareholders' Equity (Re

Common Shareholders' Equity (Restricted Stock, Performance Share Awards and Options) (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Restricted Stock Awards [Member]
Activity [Roll Forward]
Nonvested balance at beginning of year (in shares)	563,660
Granted (in shares)	291,422
Vested (in shares)	(274,144)
Forfeited (in shares)	(24,290)
Nonvested balance at end of year (in shares)	556,648	563,660
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)	$ 89.60
Granted, weighted-average grant date fair value (in dollars per share)	112.86	$ 103.58	$ 93.46
Vested, weighted-average grant date fair value (in dollars per share)	85.62
Forfeited, weighted-average grant date fair value (in dollars per share)	100.78
Nonvested balance at end of year, weighted-average grant date fair value (in dollars per share)	$ 103.26	$ 89.60
Vesting period	3 years
Performance Share Awards [Member]
Activity [Roll Forward]
Nonvested balance at beginning of year (in shares)	915,199
Granted (in shares)	604,686
Vested (in shares)	(630,773)
Forfeited (in shares)	(54,679)
Nonvested balance at end of year (in shares)	834,433	915,199
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)	$ 81.90
Granted, weighted-average grant date fair value (in dollars per share)	89.23	$ 77.12	$ 71.52
Vested, weighted-average grant date fair value (in dollars per share)	69.40
Forfeited, weighted-average grant date fair value (in dollars per share)	95.62
Nonvested balance at end of year, weighted-average grant date fair value (in dollars per share)	$ 95.76	$ 81.90
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	$ 99	$ 108	$ 85

Common Shareholders' Equity (As

Common Shareholders' Equity (Assumptions and Options) (Details) - Options [Member] - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Assumptions used to estimate the fair value of options using the Black-Scholes option pricing model [Abstract]
Expected volatility (in hundredths)	16.37%	18.91%	20.32%
Expected dividends (in hundredths)	3.16%	3.11%	3.11%
Expected term (years)	7 years	7 years	7 years
Risk-free rate (in hundredths)	1.50%	1.84%	2.17%
Option activity [Roll Forward]
Shares underlying options - Balance at beginning of year (in shares)	2,866,501
Shares underlying options - Granted (in shares)	294,889
Shares underlying options - Exercised (in shares)	(651,492)
Shares underlying options - Forfeited (in shares)	(4,690)
Shares underlying options - Balance at end of year (in shares)	2,505,208	2,866,501
Shares underlying options - Exercisable (in shares)	2,043,899
Additional disclosures pertaining to options [Abstract]
Balance at beginning of year, weighted average exercise price (in dollars per share)	$ 63.39
Granted, weighted average exercise price (in dollars per share)	111.67
Exercised, weighted average exercise price (in dollars per share)	55.37
Forfeited, weighted average exercise price (in dollars per share)	106.64
Balance at end of year, weighted average exercise price (in dollars per share)	71.08	$ 63.39
Exercisable at end of year, weighted average exercise price (in dollars per share)	$ 62.90
Balance at end of year, weighted average remaining contractual term (years)	5 years 5 months
Exercisable at end of year, weighted average remaining contractual term (years)	4 years 8 months
Balance at end of year, aggregate intrinsic value	$ 121
Exercisable at end of year, aggregate intrinsic value	$ 116
Granted, weighted average grant date fair value (in dollars per share)	$ 11.74	$ 13.62	$ 14.09
Total intrinsic value of stock options exercised	$ 42	$ 11	$ 30
Cash received from option exercises	36	9	26
Tax benefit realized from options exercised	$ 16	$ 4	$ 11
Vesting period	3 years
Vesting period, maximum term	10 years

Common Shareholders' Equity (Ad

Common Shareholders' Equity (Additional Disclosures Regarding Common and Preferred Stock) (Details)	Dec. 31, 2016$ / sharesshares
NextEra Energy [Member] | Serial Preferred Stock [Member]
Preferred stock [Abstract]
Authorized (in shares)	100,000,000
Par value (in dollars per share) | $ / shares	$ 0.01
Outstanding (in shares)	0
Preferred Stock, $100 Par Value [Member] | FPL [Member]
Preferred stock [Abstract]
Authorized (in shares)	10,414,100
Par value (in dollars per share) | $ / shares	$ 100
Preferred Stock, No Par Value [Member] | FPL [Member]
Preferred stock [Abstract]
Authorized (in shares)	5,000,000
Par value (in dollars per share) | $ / shares	$ 0
Outstanding (in shares)	0
Preferred Stock, No Par Value [Member] | FPL [Member] | Subordinated Preferred Stock [Member]
Preferred stock [Abstract]
Authorized (in shares)	5,000,000
Par value (in dollars per share) | $ / shares	$ 0

Common Shareholders' Equity (Ac

Common Shareholders' Equity (Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	$ (167)	$ (40)	$ 56
Other comprehensive income (loss) before reclassifications	45	(164)	(156)
Amounts reclassified from AOCI	52	26	58
Total other comprehensive income (loss), net of tax	97	(138)	(98)
Less other comprehensive income attributable to noncontrolling interests	0	(11)	(2)
Accumulated other comprehensive loss, ending	(70)	(167)	(40)
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	(170)	(156)	(115)
Other comprehensive income (loss) before reclassifications	0	(88)	(141)
Amounts reclassified from AOCI	70	63	98
Total other comprehensive income (loss), net of tax	70	(25)	(43)
Less other comprehensive income attributable to noncontrolling interests	0	(11)	(2)
Accumulated other comprehensive loss, ending	(100)	(170)	(156)
Accumulated Net Unrealized Investment Gain (Loss) [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	174	218	197
Other comprehensive income (loss) before reclassifications	69	(7)	62
Amounts reclassified from AOCI	(18)	(37)	(41)
Total other comprehensive income (loss), net of tax	51	(44)	21
Less other comprehensive income attributable to noncontrolling interests	0	0	0
Accumulated other comprehensive loss, ending	225	174	218
Accumulated Defined Benefit Plans Adjustment [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	(62)	(20)	23
Other comprehensive income (loss) before reclassifications	(21)	(42)	(44)
Amounts reclassified from AOCI	0	0	1
Total other comprehensive income (loss), net of tax	(21)	(42)	(43)
Less other comprehensive income attributable to noncontrolling interests	0	0	0
Accumulated other comprehensive loss, ending	(83)	(62)	(20)
Accumulated Translation Adjustment [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	(85)	(58)	(33)
Other comprehensive income (loss) before reclassifications	(5)	(27)	(25)
Amounts reclassified from AOCI	0	0	0
Total other comprehensive income (loss), net of tax	(5)	(27)	(25)
Less other comprehensive income attributable to noncontrolling interests	0	0	0
Accumulated other comprehensive loss, ending	(90)	(85)	(58)
Accumulated Income (Loss) Related to Equity Method Investee [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss, beginning	(24)	(24)	(16)
Other comprehensive income (loss) before reclassifications	2	0	(8)
Amounts reclassified from AOCI	0	0	0
Total other comprehensive income (loss), net of tax	2	0	(8)
Less other comprehensive income attributable to noncontrolling interests	0	0	0
Accumulated other comprehensive loss, ending	$ (22)	$ (24)	$ (24)

Debt (Schedule of Debt Instrume

Debt (Schedule of Debt Instruments) (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Less current maturities of long-term debt	$ 2,604	$ 2,220
Long-term debt, excluding current maturities	27,818	26,681
liabilities associated with assets held-for-sale [Member]
Debt Instrument [Line Items]
Total long-term debt	373	938
FPL [Member]
Debt Instrument [Line Items]
Unamortized debt issuance costs and discount	(108)	(114)
Total long-term debt	10,072	10,020
Less current maturities of long-term debt	367	64
Long-term debt, excluding current maturities	$ 9,705	$ 9,956
FPL [Member] | First mortgage bonds - fixed [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	4.78%	4.77%
Long-term debt, gross	$ 8,690	$ 8,690
FPL [Member] | Storm-recovery bonds - fixed [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	5.26%	5.26%
Long-term debt, gross	$ 210	$ 273
FPL [Member] | Pollution control, solid waste disposal and industrial development revenue bonds - variable [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	0.77%	0.04%
Long-term debt, gross	$ 778	$ 718
FPL [Member] | Other long-term debt - variable [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	1.66%	1.11%
Long-term debt, gross	$ 450	$ 400
FPL [Member] | Other long-term debt - fixed [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	5.09%	5.06%
Long-term debt, gross	$ 52	$ 53
Capital Holdings [Member]
Debt Instrument [Line Items]
Fair value hedge adjustment	8	24
Unamortized debt issuance costs and discount	(101)	(94)
Total long-term debt	11,206	10,567
Less current maturities of long-term debt	1,724	667
Long-term debt, excluding current maturities	$ 9,482	$ 9,900
Capital Holdings [Member] | Other long-term debt - variable [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	1.77%	1.81%
Long-term debt, gross	$ 60	$ 1,513
Capital Holdings [Member] | Other long-term debt - fixed [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	2.45%	4.55%
Long-term debt, gross	$ 924	$ 1,307
Capital Holdings [Member] | Debentures - fixed [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	2.87%	3.15%
Long-term debt, gross	$ 4,100	$ 3,100
Capital Holdings [Member] | Debentures, related to NEE's equity units - fixed [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	1.88%	1.98%
Long-term debt, gross	$ 2,200	$ 1,200
Capital Holdings [Member] | Junior subordinated debentures - primarily fixed [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	5.40%	5.84%
Long-term debt, gross	$ 3,460	$ 2,978
Capital Holdings [Member] | Japanese yen denominated senior notes - fixed [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	5.13%	5.13%
Long-term debt, gross	$ 85	$ 83
Capital Holdings [Member] | Japanese yen denominated term loans - variable [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	1.83%	1.83%
Long-term debt, gross	$ 470	$ 456
NEER [Member]
Debt Instrument [Line Items]
Unamortized debt issuance costs and premium - net	(168)	(131)
Total long-term debt	9,144	8,314
Less current maturities of long-term debt	513	1,489
Long-term debt, excluding current maturities	$ 8,631	$ 6,825
NEER [Member] | Senior secured limited-recourse bonds and notes - fixed [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	6.00%	5.88%
Long-term debt, gross	$ 2,091	$ 2,203
NEER [Member] | Senior secured limited-recourse term loans - primarily variable [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	2.78%	2.51%
Long-term debt, gross	$ 4,959	$ 3,969
NEER [Member] | Other long-term debt - primarily variable [Member]
Debt Instrument [Line Items]
Weighted-average interest rate	2.97%	2.72%
Long-term debt, gross	$ 2,262	$ 2,273
Wholly-Owned Subsidiary of NEER [Member]
Debt Instrument [Line Items]
Debt collateralized by third party note receivable	$ 490

Debt (Minimum Annual Maturities

Debt (Minimum Annual Maturities) (Details) $ in Millions	Dec. 31, 2016USD ($)
Minimum annual maturities of long-term debt [Abstract]
2,017	$ 2,604
2,018	2,118
2,019	2,606
2,020	1,842
2,021	2,712
FPL [Member]
Minimum annual maturities of long-term debt [Abstract]
2,017	367
2,018	347
2,019	251
2,020	10
2,021	$ 47

Debt (Narrative) (Details)

Debt (Narrative) (Details) $ / shares in Units, € in Millions

Sep. 01, 2016USD ($)shares

Jun. 01, 2015USD ($)shares

Aug. 31, 2016USD ($)$ / sharesshares

Sep. 30, 2015USD ($)$ / sharesshares

Nov. 30, 2013shares

Sep. 30, 2016USD ($)shares

Dec. 31, 2016USD ($)shares

Dec. 31, 2015USD ($)shares

Dec. 31, 2014shares

Feb. 28, 2017USD ($)

Feb. 23, 2017USD ($)

Dec. 31, 2016EUR (€)

Aug. 31, 2015USD ($)

May 31, 2015USD ($)

Debt Instrument [Line Items]

Weighted-average interest rate of commercial paper and short-tem borrowings (in hundredths)

1.07%

2.10%

1.07%

Issuances of common stock, net of issuance cost (in shares) | shares

4,500,000

FPL [Member]

Debt Instrument [Line Items]

Weighted-average interest rate of commercial paper and short-tem borrowings (in hundredths)

1.07%

0.83%

1.07%

NEER [Member]

Debt Instrument [Line Items]

Amount of debt outstanding under financing agreements related to Spain solar projects

$ 498,000,000

amount of noncurrent derivative liability related to spain solar projects

$ 122,000,000

NEE Equity Units 2012 [Member]

Debt Instrument [Line Items]

Debentures remarketed

$ 650,000,000

$ 600,000,000

Rate of interest on debentures after remarketing

2.056%

1.586%

Issuances of common stock, net of issuance cost (in shares) | shares

7,860,000

8,173,099

Issuances of common stock

$ 600,000,000

$ 650,000,000

NEE Equity Units 2015 [Member]

Sale of equity units [Abstract]

Amount of equity units sold

$ 700,000,000

Stated amount of each equity unit (in dollars per share) | $ / shares

$ 50

Undivided beneficial ownership interest per debenture (in hundredths)

5.00%

Principal amount of each debenture

$ 1,000

Price per share of stock purchase contract - low range (in dollars per share) | $ / shares

$ 95.35

Price per share of stock purchase contract - high range (in dollars per share) | $ / shares

$ 114.42

Number of shares (subject to antidilution adjustments) if purchased on final settlement date at less than or equal to low range threshold (in shares) | shares

0.5261

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) | shares

0.4385

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)

6.371%

Interest rate

2.36%

Rate of payments on stock purchase contracts (in hundredths)

4.011%

NEE Equity Units 2016 [Member]

Sale of equity units [Abstract]

Amount of equity units sold

$ 1,500,000,000

Stated amount of each equity unit (in dollars per share) | $ / shares

$ 50

Undivided beneficial ownership interest per debenture (in hundredths)

5.00%

Principal amount of each debenture

$ 1,000

Number of shares (subject to antidilution adjustments) if purchased on final settlement date at less than or equal to low range threshold (in shares) | shares

0.3918

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) | shares

0.3134

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)

6.123%

Interest rate

1.65%

Rate of payments on stock purchase contracts (in hundredths)

4.473%

September 2013 Equity Units [Member]

Debt Instrument [Line Items]

Debentures remarketed

$ 500,000,000

Rate of interest on debentures after remarketing

1.649%

Minimum [Member] | NEE Equity Units 2016 [Member]

Sale of equity units [Abstract]

Price Per Share of Stock Purchase Contract | $ / shares

$ 127.63

Maximum [Member] | NEE Equity Units 2016 [Member]

Sale of equity units [Abstract]

Price Per Share of Stock Purchase Contract | $ / shares

$ 159.54

Common Stock [Member]

Debt Instrument [Line Items]

Issuances of common stock, net of issuance cost (in shares) | shares

6,000,000

17,000,000

7,000,000

Issuances of common stock

$ 1,000,000

Common Stock [Member] | September 2013 Equity Units [Member]

Debt Instrument [Line Items]

Issuances of common stock, net of issuance cost (in shares) | shares

5,101,000

Issuances of common stock

$ 500,000,000

Standby Letters of Credit [Member] | Capital Holdings [Member]

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 26,000,000

€ 23

Line of Credit [Member]

Debt Instrument [Line Items]

Available capacity

10,200,000,000

Line of Credit [Member] | FPL [Member]

Debt Instrument [Line Items]

Available capacity

3,600,000,000

Revolving Credit Facility [Member] | Line of Credit [Member]

Debt Instrument [Line Items]

Available capacity

9,800,000,000

Revolving Credit Facility [Member] | Line of Credit [Member] | FPL [Member]

Debt Instrument [Line Items]

Available capacity

3,600,000,000

Revolving Credit Facility, Issuance of Letters of Credit [Member] | Line of Credit [Member]

Debt Instrument [Line Items]

Available capacity

3,400,000,000

Revolving Credit Facility, Issuance of Letters of Credit [Member] | Line of Credit [Member] | FPL [Member]

Debt Instrument [Line Items]

Available capacity

700,000,000

Letter of Credit [Member] | Line of Credit [Member]

Debt Instrument [Line Items]

Available capacity

400,000,000

Letter of Credit [Member] | Line of Credit [Member] | FPL [Member]

Debt Instrument [Line Items]

Available capacity

$ 0

Subsequent Event [Member] | Short-Term, Non-Revolving Term Loan Facility [Member] | Term Loan [Member]

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 7,500,000,000

Subsequent Event [Member] | Short-Term, Non-Revolving Term Loan Facility 1 [Member] | Term Loan [Member]

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 3,750,000,000

Subsequent Event [Member] | Short-Term, Non-Revolving Term Loan Facility 2 [Member] | Term Loan [Member]

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 3,750,000,000

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Asset retirement obligation, roll forward analysis [Roll Forward]
Beginning balance	$ 2,469	$ 1,986
Liabilities incurred	57	51
Accretion expense	138	116
Liabilities settled	(2)	(22)
Revision in estimated cash flows - net	74	338
Ending balance	2,736	2,469
Restricted funds included in special use funds [Abstract]
Restricted funds	5,434	5,064
NEER [Member]
Asset retirement obligation, roll forward analysis [Roll Forward]
Beginning balance	647	631
Liabilities incurred	56	46
Accretion expense	47	43
Liabilities settled	(2)	(2)
Revision in estimated cash flows - net	69	(71)
Ending balance	817	647
Restricted funds included in special use funds [Abstract]
Restricted funds	1,769	1,634
FPL [Member]
Asset retirement obligation, roll forward analysis [Roll Forward]
Beginning balance	1,822	1,355
Liabilities incurred	1	5
Accretion expense	91	73
Liabilities settled	0	(20)
Revision in estimated cash flows - net	5	409
Ending balance	1,919	1,822
Restricted funds included in special use funds [Abstract]
Restricted funds	$ 3,665	$ 3,430

Commitments and Contingencies85

Commitments and Contingencies (Estimated Planned Capital Expenditures) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)MW	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Planned Capital Expenditures [Line Items]
Capital expenditures	$ 3,776	$ 3,428	$ 3,067
FPL [Member]
Planned Capital Expenditures [Line Items]
2,017	5,380
2,018	3,765
2,019	4,480
2,020	3,585
2,021	4,000
Total	21,210
Capital expenditures	3,776	$ 3,428	$ 3,067
FPL [Member] | New Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
2,017	1,385
2,018	655
2,019	485
2,020	35
2,021	5
Total	2,565
FPL [Member] | Existing Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
2,017	1,240
2,018	635
2,019	680
2,020	645
2,021	600
Total	3,800
FPL [Member] | Transmission and Distribution Expenditures [Member]
Planned Capital Expenditures [Line Items]
2,017	2,190
2,018	2,010
2,019	2,860
2,020	2,475
2,021	2,945
Total	12,480
FPL [Member] | Nuclear Fuel Expenditures [Member]
Planned Capital Expenditures [Line Items]
2,017	125
2,018	190
2,019	170
2,020	210
2,021	120
Total	815
FPL [Member] | General and Other Expenditures [Member]
Planned Capital Expenditures [Line Items]
2,017	440
2,018	275
2,019	285
2,020	220
2,021	330
Total	1,550
FPL [Member] | Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
Allowance for funds used during construction (AFUDC) - 2017	81
Allowance for funds used during construction (AFUDC) - 2018	79
Allowance for funds used during construction (AFUDC) - 2019	46
Allowance for funds used during construction (AFUDC) - 2020	6
NEER [Member]
Planned Capital Expenditures [Line Items]
2,017	2,115
2,018	2,180
2,019	1,040
2,020	360
2,021	315
Total	6,010
NEER [Member] | Wind Expenditures [Member]
Planned Capital Expenditures [Line Items]
2,017	570
2,018	955
2,019	705
2,020	75
2,021	25
Total	$ 2,330
Planned New Generation To Be Added over 5 Years | MW	2,760
NEER [Member] | Solar Expenditures [Member]
Planned Capital Expenditures [Line Items]
2,017	$ 80
2,018	75
2,019	15
2,020	0
2,021	0
Total	$ 170
Planned New Generation To Be Added over 5 Years | MW	225
NEER [Member] | Nuclear Expenditures [Member]
Planned Capital Expenditures [Line Items]
2,017	$ 240
2,018	250
2,019	230
2,020	225
2,021	245
Total	1,190
NEER [Member] | Pipelines [Member]
Planned Capital Expenditures [Line Items]
2,017	890
2,018	845
2,019	50
2,020	20
2,021	10
Total	1,815
NEER [Member] | Other Expenditures [Member]
Planned Capital Expenditures [Line Items]
2,017	335
2,018	55
2,019	40
2,020	40
2,021	35
Total	505
Corporate and Other [Member]
Planned Capital Expenditures [Line Items]
2,017	45
2,018	30
2,019	85
2,020	55
2,021	35
Total	$ 250

Commitments and Contingencies86

Commitments and Contingencies (Required Capacity and/or Minimum Payments Under Contracts) (Details) $ in Millions	May 01, 2017MMBTU	Jan. 31, 2017USD ($)MW	Dec. 31, 2016USD ($)MW	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Sep. 30, 2015USD ($)
FPL [Member]
Long-term Purchase Commitment [Line Items]
Capacity payments			$ 175	$ 434	$ 485
Energy payments			126	$ 262	$ 299
FPL [Member] | Capacity Charges [Member]
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2017			75
Capacity payments and/or minimum payments - 2018			65
Capacity payments and/or minimum payments - 2019			50
Capacity payments and/or minimum payments - 2020			20
Capacity payments and/or minimum payments - 2021			20
Capacity payments and/or minimum payments - Thereafter			$ 250
FPL [Member] | Take-or-Pay Purchased Power Contract [Member]
Long-term Purchase Commitment [Line Items]
Minimum purchase commitments (in megawatts) | MW			375
FPL [Member] | Pay-for-Performance Contracts [Member]
Long-term Purchase Commitment [Line Items]
Minimum purchase commitments (in megawatts) | MW			114
FPL [Member] | Sabal Trail and Florida Southeast Connection [Member] | Forecast [Member]
Long-term Purchase Commitment [Line Items]
Time period under contracts	25 years
Long Term Purchase Commitment, Initial Volume Required | MMBTU	400,000
Long Term Purchase Commitment, Increased Volume Required | MMBTU	600,000
FPL [Member] | Natural Gas Including Transportation and Storage Contract Minimum Payments [Member]
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2017			$ 1,305
Capacity payments and/or minimum payments - 2018			900
Capacity payments and/or minimum payments - 2019			900
Capacity payments and/or minimum payments - 2020			910
Capacity payments and/or minimum payments - 2021			905
Capacity payments and/or minimum payments - Thereafter			12,065
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 - 2017			200
Capacity payments and/or minimum payments - 2018			295
Capacity payments and/or minimum payments - 2019			290
Capacity payments and/or minimum payments - 2020			360
Capacity payments and/or minimum payments - 2021			390
Capacity payments and/or minimum payments - Thereafter			7,495
FPL [Member] | Coal Including Transportation Contract Minimum Payments [Member]
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2017			125
Capacity payments and/or minimum payments - 2018			5
Capacity payments and/or minimum payments - 2019			5
Capacity payments and/or minimum payments - 2020			0
Capacity payments and/or minimum payments - 2021			0
Capacity payments and/or minimum payments - Thereafter			$ 0
FPL [Member] | Coal Fired Generation Facility [Member]
Long-term Purchase Commitment [Line Items]
Termination of Purchased Power Agreement and Purchase Price of Generation Facility						$ 521
Regulatory Assets						$ 847
Regulatory Asset, Amortization Period			9 years
NEER [Member]
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2017			$ 1,385
Capacity payments and/or minimum payments - 2018			1,380
Capacity payments and/or minimum payments - 2019			140
Capacity payments and/or minimum payments - 2020			90
Capacity payments and/or minimum payments - 2021			75
Capacity payments and/or minimum payments - Thereafter			285
NEER [Member] | Contract Group 1 [Member]
Long-term Purchase Commitment [Line Items]
Commitment amount included in capital expenditures			$ 3,100
NEER [Member] | Sabal Trail Transmission, LLC [Member]
Long-term Purchase Commitment [Line Items]
Ownership interest			42.50%
Corporate and Other [Member]
Long-term Purchase Commitment [Line Items]
Capacity payments and/or minimum payments - 2017			$ 45
Capacity payments and/or minimum payments - 2018			10
Capacity payments and/or minimum payments - 2019			0
Capacity payments and/or minimum payments - 2020			5
Capacity payments and/or minimum payments - 2021			0
Capacity payments and/or minimum payments - Thereafter			0
Commitment to invest			30
Joint Obligations due in the next year			263
Joint obligations due in second year			$ 148
Subsequent Event [Member] | Indiantown, Florida [Member] | FPL [Member] | Coal Fired Generation Facility [Member]
Long-term Purchase Commitment [Line Items]
Coal fired generating facility capacity (in megawatts) | MW		330
Termination of Purchased Power Agreement and Purchase Price of Generation Facility		$ 451
Termination of Purchased Power Agreement and Purchase Price of Generation Facility, Liabilities Assumed		218
Regulatory Assets		$ 451
Regulatory Asset, Amortization Period		9 years

Commitments and Contingencies87

Commitments and Contingencies (Insurance) (Details) $ in Millions	Dec. 31, 2016USD ($)
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	13,000
Potential Retrospective Assessments Under Secondary Financial Protection System	1,000
Potential Retrospective Assessments Under Secondary Financial Protection System Payable Per Incident Per Year	152
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
Potential Retrospective Assessment, Limited Insurance Coverage Per Occurrence Per Site, Nuclear Insurance Mutual Companies, Property Damage Decontamination And Premature Decommissioning Risks	186
Seabrook Station Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for nuclear liability secondary financial protection	15
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	3
Duane Arnold Energy Center Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for nuclear liability secondary financial protection	38
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	5
St Lucie Unit No 2 Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for nuclear liability secondary financial protection	19
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	509
Potential Retrospective Assessments Under Secondary Financial Protection System Payable Per Incident Per Year	76
Potential Retrospective Assessment, Limited Insurance Coverage Per Occurrence Per Site, Nuclear Insurance Mutual Companies, Property Damage Decontamination And Premature Decommissioning Risks	$ 112

Segment Information (Details)

Segment Information (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Percentage of operating revenues derived from the sale of electricity (in hundredths)	90.00%	92.00%	91.00%
Maximum percentage of operating revenues from foreign sources (in hundredths)	2.00%	2.00%	2.00%
Maximum percentage of long-lived assets located in foreign countries (in hundredths)	3.00%	3.00%	3.00%
NEER [Member]
Segment Reporting Information [Line Items]
Deemed capital structure of NextEra Energy Resources (in hundredths)	70.00%
NEER [Member]
Segment Reporting Information [Line Items]
Deemed capital structure of NextEra Energy Resources (in hundredths)	70.00%

Segment Information - Schedule

Segment Information - Schedule of Segment Information (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
Segment Reporting Information [Line Items]
Operating revenues	$ 3,699	$ 4,805	$ 3,817	$ 3,835	$ 4,069	$ 4,954	$ 4,358	$ 4,104	$ 16,155		$ 17,486		$ 17,021
Operating expenses - net									11,547		12,854		12,637
Interest expense									1,093		1,211		1,261
Interest income									82		86		80
Depreciation and amortization									3,077		2,831		2,551
Equity in losses (earnings) of equity method investees									148		107		93
Income tax expense (benefit)									1,383		1,228		1,176
Net Income (loss)	1,017	789	544	654	510	882	720	650	3,005		2,762		2,469
Net income (loss) attributable to parent	966	753	540	653	507	879	716	650	2,912		2,752		2,465
Capital expenditures, independent power and other investments and nuclear fuel purchases									9,636		8,377		7,017
Property, plant and equipment	87,013				80,330				87,013		80,330		73,639
Accumulated depreciation and amortization	20,101				18,944				20,101		18,944		17,934
Total assets	89,993				82,479				89,993		82,479		74,605
Investment in equity method investees	1,767				1,063				1,767		1,063		663
NEER [Member]
Segment Reporting Information [Line Items]
Operating revenues									4,893		5,444		5,196
Operating expenses - net									3,419		3,865		3,727
Interest expense									732		625		667
Interest income									34		28		26
Depreciation and amortization									1,366		1,183		1,051
Equity in losses (earnings) of equity method investees									119		103		95
Income tax expense (benefit)									242		289		283
Net Income (loss)									1,218		1,102		993
Net income (loss) attributable to parent									1,125		1,092		989
Capital expenditures, independent power and other investments and nuclear fuel purchases									5,521		4,661		3,701
Property, plant and equipment	37,644				33,340				37,644		33,340		30,178
Accumulated depreciation and amortization	7,655				6,640				7,655		6,640		6,268
Total assets	41,743				37,647				41,743		37,647		32,896
Investment in equity method investees	1,661				983				1,661		983		617
FPL [Member]
Segment Reporting Information [Line Items]
Operating expenses - net									7,737		8,674		8,593
Interest expense									456		445		439
Interest income									2		7		3
Equity in losses (earnings) of equity method investees									0		0		0
Net Income (loss)									1,727		1,648		1,517
Net income (loss) attributable to parent									1,727		1,648		1,517
Capital expenditures, independent power and other investments and nuclear fuel purchases									3,934		3,633		3,241
Property, plant and equipment	48,313				45,383				48,313		45,383		41,938
Accumulated depreciation and amortization - FPL	12,304				11,862				12,304		11,862		11,282
Total assets	45,501				42,523				45,501		42,523		39,222
Investment in equity method investees	0				0				0		0		0
Corporate and Other [Member]
Segment Reporting Information [Line Items]
Operating revenues									367		391		404
Operating expenses - net									391		315		317
Interest expense									(95)		141		155
Interest income									46		51		51
Depreciation and amortization									60		72		68
Equity in losses (earnings) of equity method investees									29		4		(2)
Income tax expense (benefit)									90		(18)		(17)
Net Income (loss)									60		12		(41)
Net income (loss) attributable to parent									60		12		(41)
Capital expenditures, independent power and other investments and nuclear fuel purchases									181		83		75
Property, plant and equipment	1,056				1,607				1,056		1,607		1,523
Accumulated depreciation and amortization	142				442				142		442		384
Total assets	2,749				2,309				2,749		2,309		2,487
Investment in equity method investees	106				80				106		80		46
FPL [Member]
Segment Reporting Information [Line Items]
Operating revenues	2,558	3,283	2,750	2,303	2,839	3,274	2,996	2,541	10,895		11,651		11,421
Operating expenses - net									7,737		8,674		8,593
Interest expense									456		445		439
Depreciation and amortization									1,651		1,576		1,432
Income tax expense (benefit)									1,051		957		910
Net income (loss) attributable to parent	371	$ 515	$ 448	$ 393	365	$ 489	$ 435	$ 359	1,727	[1]	1,648	[1]	$ 1,517	[1]
Accumulated depreciation and amortization - FPL	12,304				11,862				12,304		11,862
Total assets	$ 45,501				$ 42,523				$ 45,501		$ 42,523
[1]	FPL's comprehensive income is the same as reported net income

Summarized Financial Informat90

Summarized Financial Information of NEECH - Income Statement (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating revenues	$ 3,699	$ 4,805	$ 3,817	$ 3,835	$ 4,069	$ 4,954	$ 4,358	$ 4,104	$ 16,155	$ 17,486	$ 17,021
Operating expenses - net									(11,547)	(12,854)	(12,637)
Interest expense									(1,093)	(1,211)	(1,261)
Equity in earnings of subsidiaries									0	0	0
Other income (deductions) - net									873	569	522
INCOME (LOSS) BEFORE INCOME TAXES									4,388	3,990	3,645
Income tax expense (benefit)									1,383	1,228	1,176
Net Income (loss)	1,017	789	544	654	510	882	720	650	3,005	2,762	2,469
LESS NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS									93	10	4
Net income (loss) attributable to parent	$ 966	$ 753	$ 540	$ 653	$ 507	$ 879	$ 716	$ 650	2,912	2,752	2,465
NEE (Guarantor) [Member]
Operating revenues									0	0	0
Operating expenses - net									(20)	(17)	(19)
Interest expense									(1)	(4)	(6)
Equity in earnings of subsidiaries									2,956	2,754	2,494
Other income (deductions) - net									5	1	1
INCOME (LOSS) BEFORE INCOME TAXES									2,940	2,734	2,470
Income tax expense (benefit)									28	(18)	5
Net Income (loss)									2,912	2,752	2,465
LESS NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS									0	0	0
Net income (loss) attributable to parent									2,912	2,752	2,465
NEECH [Member]
Operating revenues									5,283	5,849	5,614
Operating expenses - net									(3,663)	(4,142)	(4,039)
Interest expense									(636)	(764)	(819)
Equity in earnings of subsidiaries									0	0	0
Other income (deductions) - net									793	498	487
INCOME (LOSS) BEFORE INCOME TAXES									1,777	1,441	1,243
Income tax expense (benefit)									354	299	262
Net Income (loss)									1,423	1,142	981
LESS NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS									93	10	4
Net income (loss) attributable to parent									1,330	1,132	977
Other [Member]
Operating revenues									10,872	11,637	11,407
Operating expenses - net									(7,864)	(8,695)	(8,579)
Interest expense									(456)	(443)	(436)
Equity in earnings of subsidiaries									(2,956)	(2,754)	(2,494)
Other income (deductions) - net									75	70	34
INCOME (LOSS) BEFORE INCOME TAXES									(329)	(185)	(68)
Income tax expense (benefit)									1,001	947	909
Net Income (loss)									(1,330)	(1,132)	(977)
LESS NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS									0	0	0
Net income (loss) attributable to parent									$ (1,330)	$ (1,132)	$ (977)

Summarized Financial Informat91

Summarized Financial Information of NEECH - Condensed Consolidating Statements of Comprehensive Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Comprehensive income (loss) attributable to NEE	$ 3,009	$ 2,625	$ 2,369
NEE (Guarantor) [Member]
Condensed Financial Statements, Captions [Line Items]
Comprehensive income (loss) attributable to NEE	$ 3,009	2,625	2,369
NEECH [Member]
Condensed Financial Statements, Captions [Line Items]
Ownership interest	100.00%
Comprehensive income (loss) attributable to NEE	$ 1,448	1,049	924
Other [Member]
Condensed Financial Statements, Captions [Line Items]
Comprehensive income (loss) attributable to NEE	$ (1,448)	$ (1,049)	$ (924)

Summarized Financial Informat92

Summarized Financial Information of NEECH - Balance Sheets (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	$ 87,013	$ 80,330	$ 73,639
Accumulated depreciation and amortization	(20,101)	(18,944)
Total property, plant and equipment - net	66,912	61,386
CURRENT ASSETS
Cash and cash equivalents	1,292	571	577	$ 438	$ 438
Receivables	2,439	2,265
Other	3,678	3,959
Total current assets	7,409	6,795
OTHER ASSETS
Investment in subsidiaries	0	0
Other	15,672	14,298
Total other assets	15,672	14,298
TOTAL ASSETS	89,993	82,479	74,605
CAPITALIZATION
Common shareholders' equity	24,341	22,574
Noncontrolling interests	990	538
Long-term debt	27,818	26,681
Total capitalization	53,149	49,793
CURRENT LIABILITIES
Debt due within one year	3,022	3,006
Accounts payable	3,447	2,529
Other	4,450	4,572
Total current liabilities	10,919	10,107
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	2,736	2,469
Deferred income taxes	11,101	9,827
Other	12,088	10,283
Total other liabilities and deferred credits	25,925	22,579
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	89,993	82,479
NEE (Guarantor) [Member]
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	28	27
Accumulated depreciation and amortization	(18)	(16)
Total property, plant and equipment - net	10	11
CURRENT ASSETS
Cash and cash equivalents	1	0	0	0
Receivables	88	90
Other	2	4
Total current assets	91	94
OTHER ASSETS
Investment in subsidiaries	24,323	22,544
Other	867	823
Total other assets	25,190	23,367
TOTAL ASSETS	25,291	23,472
CAPITALIZATION
Common shareholders' equity	24,341	22,574
Noncontrolling interests	0	0
Long-term debt	0	0
Total capitalization	24,341	22,574
CURRENT LIABILITIES
Debt due within one year	0	0
Accounts payable	1	4
Other	231	252
Total current liabilities	232	256
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	0	0
Deferred income taxes	82	157
Other	636	485
Total other liabilities and deferred credits	718	642
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	25,291	23,472
NEECH [Member]
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	38,671	34,921
Accumulated depreciation and amortization	(7,778)	(7,067)
Total property, plant and equipment - net	30,893	27,854
CURRENT ASSETS
Cash and cash equivalents	1,258	546	562	418
Receivables	1,615	1,510
Other	1,877	2,443
Total current assets	4,750	4,499
OTHER ASSETS
Investment in subsidiaries	0	0
Other	8,992	7,790
Total other assets	8,992	7,790
TOTAL ASSETS	44,635	40,143
CAPITALIZATION
Common shareholders' equity	7,699	6,990
Noncontrolling interests	990	538
Long-term debt	18,112	16,725
Total capitalization	26,801	24,253
CURRENT LIABILITIES
Debt due within one year	2,237	2,786
Accounts payable	2,668	1,919
Other	2,624	3,003
Total current liabilities	7,529	7,708
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	816	647
Deferred income taxes	3,002	2,396
Other	6,487	5,139
Total other liabilities and deferred credits	10,305	8,182
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	44,635	40,143
Other [Member]
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	48,314	45,382
Accumulated depreciation and amortization	(12,305)	(11,861)
Total property, plant and equipment - net	36,009	33,521
CURRENT ASSETS
Cash and cash equivalents	33	25	$ 15	$ 20
Receivables	736	665
Other	1,799	1,512
Total current assets	2,568	2,202
OTHER ASSETS
Investment in subsidiaries	(24,323)	(22,544)
Other	5,813	5,685
Total other assets	(18,510)	(16,859)
TOTAL ASSETS	20,067	18,864
CAPITALIZATION
Common shareholders' equity	(7,699)	(6,990)
Noncontrolling interests	0	0
Long-term debt	9,706	9,956
Total capitalization	2,007	2,966
CURRENT LIABILITIES
Debt due within one year	785	220
Accounts payable	778	606
Other	1,595	1,317
Total current liabilities	3,158	2,143
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,920	1,822
Deferred income taxes	8,017	7,274
Other	4,965	4,659
Total other liabilities and deferred credits	14,902	13,755
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$ 20,067	$ 18,864

Summarized Financial Informat93

Summarized Financial Information of NEECH - Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net cash provided by operating activities	$ 6,336	$ 6,116	$ 5,500
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	(9,636)	(8,377)	(7,017)
Capital contributions from NEE	0	0	0
Cash grants under the Recovery Act	335	8	343
Sale of independent power and other investments of NEER	658	52	307
Proceeds from sale or maturity of securities in special use funds and other investments	3,776	4,851	4,621
Purchases of securities in special use funds and other investments	(3,829)	(4,982)	(4,767)
Proceeds from the sale of a noncontrolling interest in subsidiaries	645	345	438
Other - net	(59)	98	(286)
Net cash used in investing activities	(8,110)	(8,005)	(6,361)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	5,657	5,772	5,054
Retirements of long-term debt	(3,310)	(3,972)	(4,750)
Proceeds from differential membership investors	1,859	761	978
Proceeds from other short-term debt	500	1,225	500
Repayments of other short-term debt	(662)	(813)	(500)
Net change in commercial paper	(106)	(768)	451
Issuances of common stock - net	537	1,298	633
Dividends on common stock	(1,612)	(1,385)	(1,261)
Dividends to NEE	0	0	0
Other - net	(368)	(235)	(105)
Net cash provided by (used in) financing activities	2,495	1,883	1,000
Net increase (decrease) in cash and cash equivalents	721	(6)	139
Cash and cash equivalents at beginning of year	571	577	438
Cash and cash equivalents at end of year	1,292	571	577
NEE (Guarantor) [Member]
Net cash provided by operating activities	1,897	1,659	1,615
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	(1)	0	(1)
Capital contributions from NEE	(745)	(1,480)	(912)
Cash grants under the Recovery Act	0	0	0
Sale of independent power and other investments of NEER	0	0	0
Proceeds from sale or maturity of securities in special use funds and other investments	0	0	0
Purchases of securities in special use funds and other investments	0	0	0
Proceeds from the sale of a noncontrolling interest in subsidiaries	0	0	0
Other - net	0	0	10
Net cash used in investing activities	(746)	(1,480)	(903)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	0	0	0
Retirements of long-term debt	0	0	0
Proceeds from differential membership investors	0	0	0
Proceeds from other short-term debt	0	0	0
Repayments of other short-term debt	0	0	0
Net change in commercial paper	0	0	0
Issuances of common stock - net	537	1,298	633
Dividends on common stock	(1,612)	(1,385)	(1,261)
Dividends to NEE	0	0	0
Other - net	(75)	(92)	(84)
Net cash provided by (used in) financing activities	(1,150)	(179)	(712)
Net increase (decrease) in cash and cash equivalents	1	0	0
Cash and cash equivalents at beginning of year	0	0	0
Cash and cash equivalents at end of year	1	0	0
NEECH [Member]
Net cash provided by operating activities	2,171	2,488	1,976
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	(5,701)	(4,744)	(3,741)
Capital contributions from NEE	0	0	0
Cash grants under the Recovery Act	335	8	343
Sale of independent power and other investments of NEER	658	52	307
Proceeds from sale or maturity of securities in special use funds and other investments	1,281	1,120	1,272
Purchases of securities in special use funds and other investments	(1,323)	(1,190)	(1,321)
Proceeds from the sale of a noncontrolling interest in subsidiaries	645	345	438
Other - net	(40)	106	(64)
Net cash used in investing activities	(4,145)	(4,303)	(2,766)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	5,349	4,689	4,057
Retirements of long-term debt	(3,048)	(3,421)	(4,395)
Proceeds from differential membership investors	1,859	761	978
Proceeds from other short-term debt	0	1,125	500
Repayments of other short-term debt	(212)	(813)	(500)
Net change in commercial paper	(318)	318	(487)
Issuances of common stock - net	0	0	0
Dividends on common stock	0	0	0
Dividends to NEE	(650)	(698)	812
Other - net	(294)	(162)	(31)
Net cash provided by (used in) financing activities	2,686	1,799	934
Net increase (decrease) in cash and cash equivalents	712	(16)	144
Cash and cash equivalents at beginning of year	546	562	418
Cash and cash equivalents at end of year	1,258	546	562
Other [Member]
Net cash provided by operating activities	2,268	1,969	1,909
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	(3,934)	(3,633)	(3,275)
Capital contributions from NEE	745	1,480	912
Cash grants under the Recovery Act	0	0	0
Sale of independent power and other investments of NEER	0	0	0
Proceeds from sale or maturity of securities in special use funds and other investments	2,495	3,731	3,349
Purchases of securities in special use funds and other investments	(2,506)	(3,792)	(3,446)
Proceeds from the sale of a noncontrolling interest in subsidiaries	0	0	0
Other - net	(19)	(8)	(232)
Net cash used in investing activities	(3,219)	(2,222)	(2,692)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	308	1,083	997
Retirements of long-term debt	(262)	(551)	(355)
Proceeds from differential membership investors	0	0	0
Proceeds from other short-term debt	500	100	0
Repayments of other short-term debt	(450)	0	0
Net change in commercial paper	212	(1,086)	938
Issuances of common stock - net	0	0	0
Dividends on common stock	0	0	0
Dividends to NEE	650	698	(812)
Other - net	1	19	10
Net cash provided by (used in) financing activities	959	263	778
Net increase (decrease) in cash and cash equivalents	8	10	(5)
Cash and cash equivalents at beginning of year	25	15	20
Cash and cash equivalents at end of year	$ 33	$ 25	$ 15

Quarterly Data (Unaudited) (Det

Quarterly Data (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
Condensed consolidated quarterly financial information [Abstract]
Operating revenues	$ 3,699	$ 4,805	$ 3,817	$ 3,835	$ 4,069	$ 4,954	$ 4,358	$ 4,104	$ 16,155		$ 17,486		$ 17,021
Operating income	926	1,279	1,169	1,234	876	1,481	1,146	1,129	4,608		4,632		4,384
Net income	1,017	789	544	654	510	882	720	650	3,005		2,762		2,469
Net income (loss) attributable to parent	$ 966	$ 753	$ 540	$ 653	$ 507	$ 879	$ 716	$ 650	$ 2,912		$ 2,752		$ 2,465
Basic EPS - Net income (in dollars per share)	$ 2.07	$ 1.63	$ 1.17	$ 1.42	$ 1.10	$ 1.94	$ 1.61	$ 1.47
Diluted EPS - Net income (in dollars per share)	2.06	1.62	1.16	1.41	1.10	1.93	1.59	1.45
Dividends per share of common stock (in dollars per share)	0.87	0.87	0.87	0.87	0.77	0.77	0.77	0.77	$ 3.48		$ 3.08		$ 2.90
High common stock sales price (in dollars per share)	128.46	131.98	130.43	119.37	105.85	109.98	106.63	112.64
Low common stock sales price (in dollars per share)	$ 110.49	$ 120.22	$ 112.44	$ 102.20	$ 95.84	$ 93.74	$ 97.23	$ 97.48
FPL [Member]
Condensed consolidated quarterly financial information [Abstract]
Operating revenues	$ 2,558	$ 3,283	$ 2,750	$ 2,303	$ 2,839	$ 3,274	$ 2,996	$ 2,541	$ 10,895		$ 11,651		$ 11,421
Operating income	694	921	828	714	674	855	780	667	3,158		2,977		2,828
Net income (loss) attributable to parent	$ 371	$ 515	$ 448	393	$ 365	$ 489	$ 435	$ 359	$ 1,727	[1]	$ 1,648	[1]	$ 1,517	[1]
Adjustments for New Accounting Pronouncement [Member]
Condensed consolidated quarterly financial information [Abstract]
Net income				$ 17
Basic and earnings per share (in dollars per share)				$ 0.04
[1]	FPL's comprehensive income is the same as reported net income