10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period endedMarch 31, 2014

Commission File Number	Exact name of registrants as specified in their charters, address of principal executive offices and registrants' telephone number	IRS Employer Identification Number
1-8841	NEXTERA ENERGY, INC.	59-2449419
2-27612	FLORIDA POWER & LIGHT COMPANY	59-0247775
	700 Universe Boulevard Juno Beach, Florida 33408 (561) 694-4000

State or other jurisdiction of incorporation or organization:  Florida

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

NextEra Energy, Inc.    Yes þ    No o                                                                     Florida Power & Light Company    Yes þ    No o

Indicate by check mark whether the registrants have submitted electronically and posted on their corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months.

NextEra Energy, Inc.    Yes þ    No o                                                                     Florida Power & Light Company    Yes þ    No o

Indicate by check mark whether the registrants are a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company.  See definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Securities Exchange Act of 1934.

NextEra Energy, Inc.	Large Accelerated Filer þ	Accelerated Filer ¨	Non-Accelerated Filer ¨	Smaller Reporting Company ¨
Florida Power & Light Company	Large Accelerated Filer ¨	Accelerated Filer ¨	Non-Accelerated Filer þ	Smaller Reporting Company ¨

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

The number of shares outstanding of NextEra Energy, Inc. common stock, as of the latest practicable date:  Common Stock, $0.01 par value, outstanding as of March 31, 2014: 436,118,602 shares.

As of March 31, 2014, there were issued and outstanding 1,000 shares of Florida Power & Light Company common stock, without par value, all of which were held, beneficially and of record, by NextEra Energy, Inc.

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

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

TABLE OF CONTENTS

		Page No.
Forward-Looking Statements		3
	PART I - FINANCIAL INFORMATION
Item 1.	Financial Statements	6
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	37
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	50
Item 4.	Controls and Procedures	50
	PART II - OTHER INFORMATION
Item 1.	Legal Proceedings	50
Item 1A.	Risk Factors	50
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	50
Item 5.	Other Information	51
Item 6.	Exhibits	52
Signatures		53

NextEra Energy, Inc., Florida Power & Light Company, NextEra Energy Capital Holdings, Inc. and NextEra Energy Resources, LLC each has subsidiaries and affiliates with names that may include NextEra Energy, FPL, NextEra Energy Resources, NextEra, FPL Group Capital, FPL Energy, FPLE and similar references.  For convenience and simplicity, in this report the terms NEE, FPL, NEECH and NEER are sometimes used as abbreviated references to specific subsidiaries, affiliates or groups of subsidiaries or affiliates.  The precise meaning depends on the context.

2

FORWARD-LOOKING STATEMENTS

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

Regulatory, Legislative and Legal Risks

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

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

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

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

• Any reductions to, or the elimination of, governmental incentives that support renewable energy, including, but not limited to, tax incentives, renewable portfolio standards or feed-in tariffs, or the imposition of additional taxes or other assessments on renewable energy, could result in, among other items, the lack of a satisfactory market for the development of new renewable energy projects, NextEra Energy Resources, LLC (NEER) abandoning the development of renewable energy projects, a loss of NEER's investments in renewable energy projects and reduced project returns, any of which could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.

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

• NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected if the rules implementing the Dodd-Frank Wall Street Reform and Consumer Protection Act broaden the scope of its provisions regarding the regulation of over-the-counter (OTC) financial derivatives and make certain provisions applicable to NEE and FPL.

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

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

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

• Changes in tax laws, as well as judgments and estimates used in the determination of tax-related asset and liability amounts, could adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.

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

Operational Risks

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

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

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

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

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

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

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

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

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

• Sales of power on the spot market or on a short-term contractual basis may cause NEE's results of operations to be volatile.

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

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

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

• If power transmission or natural gas, nuclear fuel or other commodity transportation facilities are unavailable or disrupted, FPL's and NEER's ability to sell and deliver power or natural gas may be limited.

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

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

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

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

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

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

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

• Increasing costs associated with health care plans may materially adversely affect NEE's and FPL's results of operations.

• NEE's and FPL's business, financial condition, results of operations and prospects could be negatively affected by the lack of a qualified workforce or the loss or retirement of key employees.

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

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

Nuclear Generation Risks

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

• In the event of an incident at any nuclear generation facility in the United States (U.S.) or at certain nuclear generation facilities in Europe, NEE and FPL could be assessed significant retrospective assessments and/or retrospective insurance

4

premiums as a result of their participation in a secondary financial protection system and nuclear insurance mutual companies.

• U.S. Nuclear Regulatory Commission (NRC) orders or new regulations related to increased security measures and any future safety requirements promulgated by the NRC could require NEE and FPL to incur substantial operating and capital expenditures at their nuclear generation facilities.

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

• Various hazards posed to nuclear generation facilities, along with increased public attention to and awareness of such hazards, could result in increased nuclear licensing or compliance costs which are difficult or impossible to predict and could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

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

Liquidity, Capital Requirements and Common Stock Risks

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

• NEE's, NextEra Energy Capital Holdings, Inc.'s (NEECH) and FPL's inability to maintain their current credit ratings may adversely affect NEE's and FPL's liquidity and results of operations, limit the ability of NEE and FPL to grow their business, and increase interest costs.

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

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

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

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

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

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

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

These factors should be read together with the risk factors included in Part I, Item 1A. Risk Factors in NEE's and FPL's Annual Report on Form 10-K for the year ended December 31, 2013 (2013 Form 10-K), and investors should refer to that section of the 2013 Form 10-K. Any forward-looking statement speaks only as of the date on which such statement is made, and NEE and FPL undertake no obligation to update any forward-looking statement to reflect events or circumstances, including, but not limited to, unanticipated events, after the date on which such statement is made, unless otherwise required by law.  New factors emerge from time to time and it is not possible for management to predict all of such factors, nor can it assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained or implied in any forward-looking statement.

Website Access to U.S. Securities and Exchange Commission (SEC) Filings.  NEE and FPL make their SEC filings, including the annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports, available free of charge on NEE's internet website, www.nexteraenergy.com, as soon as reasonably practicable after those documents are electronically filed with or furnished to the SEC.  The information and materials available on NEE's website (or any of its subsidiaries' websites) are not incorporated by reference into this combined Form 10-Q.  The SEC maintains an internet website that contains reports, proxy and information statements and other information regarding registrants that file electronically with the SEC at www.sec.gov.

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PART I - FINANCIAL INFORMATION

Item 1.  Financial Statements

NEXTERA ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(millions, except per share amounts)

(unaudited)

	Three Months Ended   March 31,
	2014			2013
OPERATING REVENUES	$	3,674		$	3,279
OPERATING EXPENSES
Fuel, purchased power and interchange	1,397			1,065
Other operations and maintenance	756			756
Impairment charge	—			300
Depreciation and amortization	463			419
Taxes other than income taxes and other	320			305
Total operating expenses	2,936			2,845
OPERATING INCOME	738			434
OTHER INCOME (DEDUCTIONS)
Interest expense	(319		)	(272		)
Benefits associated with differential membership interests - net	65			40
Allowance for equity funds used during construction	15			26
Interest income	22			19
Gains on disposal of assets - net	44			12
Gain (loss) associated with Maine fossil	21			(67		)
Other - net	(3		)	(7		)
Total other deductions - net	(155		)	(249		)
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	583			185
INCOME TAXES	153			144
INCOME FROM CONTINUING OPERATIONS	430			41
GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	—			231
NET INCOME	$	430		$	272
Basic earnings per share of common stock:
Continuing operations	$	0.99		$	0.10
Discontinued operations	—			0.55
Net income	$	0.99		$	0.65
Earnings per share of common stock - assuming dilution:
Continuing operations	$	0.98		$	0.10
Discontinued operations	—			0.54
Net income	$	0.98		$	0.64
Dividends per share of common stock	$	0.725		$	0.66
Weighted-average number of common shares outstanding:
Basic	433.5			421.0
Assuming dilution	438.2			423.7

This report should be read in conjunction with the Notes to Condensed Consolidated Financial Statements (Notes) herein and the Notes to Consolidated Financial Statements appearing in the 2013 Form 10-K.

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NEXTERA ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(millions)

(unaudited)

	Three Months Ended   March 31,
	2014			2013
NET INCOME	$	430		$	272
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX
Net unrealized gains (losses) on cash flow hedges:
Effective portion of net unrealized gains (losses) (net of $11 tax benefit and $27 tax expense, respectively)	(18		)	65
Reclassification from accumulated other comprehensive income to net income (net of $5 and $13 tax expense, respectively)	9			21
Net unrealized gains (losses) on available for sale securities:
Net unrealized gains on securities still held (net of $10 and $26 tax expense, respectively)	13			40
Reclassification from accumulated other comprehensive income to net income (net of $15 and $4 tax benefit, respectively)	(25		)	(6		)
Defined benefit pension and other benefits plans (net of $3 and $4 tax expense, respectively)	5			7
Net unrealized losses on foreign currency translation (net of $8 and $5 tax benefit, respectively)	(17		)	(9		)
Other comprehensive income (loss) related to equity method investee (net of $1 tax benefit in 2014)	(2		)	1
Total other comprehensive income (loss), net of tax	(35		)	119
COMPREHENSIVE INCOME	$	395		$	391

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2013 Form 10-K.

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NEXTERA ENERGY, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(millions, except par value)

(unaudited)

	March 31, 2014			December 31, 2013
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	$	63,428		$	62,699
Nuclear fuel	2,166			2,059
Construction work in progress	4,773			4,690
Less accumulated depreciation and amortization	(17,061		)	(16,728		)
Total property, plant and equipment - net ($5,077 and $5,127 related to VIEs, respectively)	53,306			52,720
CURRENT ASSETS
Cash and cash equivalents	488			438
Customer receivables, net of allowances of $18 and $14, respectively	1,904			1,777
Other receivables	647			512
Materials, supplies and fossil fuel inventory	1,148			1,153
Regulatory assets:
Deferred clause and franchise expenses	166			192
Other	116			116
Derivatives	533			498
Deferred income taxes	754			753
Other	385			403
Total current assets	6,141			5,842
OTHER ASSETS
Special use funds	4,866			4,780
Other investments	1,148			1,121
Prepaid benefit costs	1,476			1,456
Regulatory assets:
Securitized storm-recovery costs ($220 and $228 related to a VIE, respectively)	358			372
Other	440			426
Derivatives	984			1,163
Other	1,612			1,426
Total other assets	10,884			10,744
TOTAL ASSETS	$	70,331		$	69,306
CAPITALIZATION
Common stock ($0.01 par value, authorized shares - 800; outstanding shares - 436 and 435, respectively)	$	4		$	4
Additional paid-in capital	6,451			6,411
Retained earnings	11,684			11,569
Accumulated other comprehensive income	21			56
Total common shareholders' equity	18,160			18,040
Long-term debt ($1,190 and $1,207 related to VIEs, respectively)	23,824			23,969
Total capitalization	41,984			42,009
CURRENT LIABILITIES
Commercial paper	1,869			691
Current maturities of long-term debt	3,822			3,766
Accounts payable	1,450			1,200
Customer deposits	452			452
Accrued interest and taxes	555			473
Derivatives	815			838
Accrued construction-related expenditures	458			839
Other	871			930
Total current liabilities	10,292			9,189
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,877			1,850
Deferred income taxes	8,306			8,144
Regulatory liabilities:
Accrued asset removal costs	1,722			1,839
Asset retirement obligation regulatory expense difference	2,122			2,082
Other	457			462
Derivatives	396			473
Deferral related to differential membership interests - VIEs	1,933			2,001
Other	1,242			1,257
Total other liabilities and deferred credits	18,055			18,108
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	70,331		$	69,306

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2013 Form 10-K.

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NEXTERA ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(millions)

(unaudited)

	Three Months Ended   March 31,
	2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	430		$	272
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	463			419
Nuclear fuel and other amortization	88			81
Impairment charge	—			300
Unrealized losses on marked to market energy contracts	124			42
Deferred income taxes	190			363
Benefits associated with differential membership interests - net	(65		)	(40		)
Allowance for equity funds used during construction	(15		)	(26		)
Gains on disposal of assets - net	(44		)	(12		)
Gain from discontinued operations, net of income taxes	—			(231		)
Loss (gain) associated with Maine fossil	(21		)	67
Other - net	47			67
Changes in operating assets and liabilities:
Customer and other receivables	(90		)	136
Materials, supplies and fossil fuel inventory	9			(25		)
Other current assets	(24		)	(10		)
Other assets	(97		)	(25		)
Accounts payable and customer deposits	162			42
Margin cash collateral	(84		)	(2		)
Income taxes	(42		)	(205		)
Interest and other taxes	122			74
Other current liabilities	(161		)	(219		)
Other liabilities	25			14
Net cash provided by operating activities	1,017			1,082
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL	(999		)	(810		)
Independent power and other investments of NEER	(752		)	(972		)
Cash grants under the American Recovery and Reinvestment Act of 2009	—			170
Nuclear fuel purchases	(91		)	(24		)
Other capital expenditures and other investments	(24		)	(61		)
Sale of independent power investments	53			—
Change in loan proceeds restricted for construction	(28		)	112
Proceeds from sale or maturity of securities in special use funds and other investments	1,451			1,005
Purchases of securities in special use funds and other investments	(1,481		)	(1,014		)
Other - net	29			16
Net cash used in investing activities	(1,842		)	(1,578		)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	655			623
Retirements of long-term debt	(717		)	(923		)
Payments to differential membership investors	(22		)	(20		)
Net change in short-term debt	1,179			966
Issuances of common stock - net	25			8
Dividends on common stock	(315		)	(279		)
Other - net	70			7
Net cash provided by financing activities	875			382
Net increase (decrease) in cash and cash equivalents	50			(114		)
Cash and cash equivalents at beginning of period	438			329
Cash and cash equivalents at end of period	$	488		$	215
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	$	802		$	674
Sale of hydropower generation plants through assumption of debt by buyer	$	—		$	700
Changes in property, plant and equipment as a result of a settlement	$	128		$	—

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2013 Form 10-K.

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FLORIDA POWER & LIGHT COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(millions)

(unaudited)

	Three Months Ended   March 31,
	2014			2013
OPERATING REVENUES	$	2,535		$	2,188
OPERATING EXPENSES
Fuel, purchased power and interchange	1,036			820
Other operations and maintenance	384			385
Depreciation and amortization	209			181
Taxes other than income taxes and other	274			259
Total operating expenses	1,903			1,645
OPERATING INCOME	632			543
OTHER INCOME (DEDUCTIONS)
Interest expense	(102		)	(102		)
Allowance for equity funds used during construction	15			18
Other - net	1			1
Total other deductions - net	(86		)	(83		)
INCOME BEFORE INCOME TAXES	546			460
INCOME TAXES	199			172
NET INCOME(a)	$	347		$	288

_______________________

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

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2013 Form 10-K.

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FLORIDA POWER & LIGHT COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

(millions, except share amount)

(unaudited)

	March 31, 2014			December 31, 2013
ELECTRIC UTILITY PLANT
Plant in service and other property	$	37,132		$	36,838
Nuclear fuel	1,329			1,240
Construction work in progress	2,241			1,818
Less accumulated depreciation and amortization	(11,085		)	(10,944		)
Total electric utility plant - net	29,617			28,952
CURRENT ASSETS
Cash and cash equivalents	38			19
Customer receivables, net of allowances of $4 and $5, respectively	706			757
Other receivables	111			137
Materials, supplies and fossil fuel inventory	764			742
Regulatory assets:
Deferred clause and franchise expenses	166			192
Other	107			105
Other	237			261
Total current assets	2,129			2,213
OTHER ASSETS
Special use funds	3,327			3,273
Prepaid benefit costs	1,154			1,142
Regulatory assets:
Securitized storm-recovery costs ($220 and $228 related to a VIE, respectively)	358			372
Other	407			396
Other	197			140
Total other assets	5,443			5,323
TOTAL ASSETS	$	37,189		$	36,488
CAPITALIZATION
Common stock (no par value, 1,000 shares authorized, issued and outstanding)	$	1,373		$	1,373
Additional paid-in capital	6,278			6,179
Retained earnings	5,879			5,532
Total common shareholder's equity	13,530			13,084
Long-term debt ($300 and $331 related to a VIE, respectively)	8,443			8,473
Total capitalization	21,973			21,557
CURRENT LIABILITIES
Commercial paper	324			204
Current maturities of long-term debt	358			356
Accounts payable	691			611
Customer deposits	447			447
Accrued interest and taxes	382			272
Accrued construction-related expenditures	150			202
Other	419			438
Total current liabilities	2,771			2,530
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,302			1,285
Deferred income taxes	6,444			6,355
Regulatory liabilities:
Accrued asset removal costs	1,722			1,839
Asset retirement obligation regulatory expense difference	2,122			2,082
Other	387			386
Other	468			454
Total other liabilities and deferred credits	12,445			12,401
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	37,189		$	36,488

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2013 Form 10-K.

11

FLORIDA POWER & LIGHT COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(millions)

(unaudited)

	Three Months Ended   March 31,
	2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	347		$	288
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	209			181
Nuclear fuel and other amortization	47			34
Deferred income taxes	168			238
Allowance for equity funds used during construction	(15		)	(18		)
Other - net	10			23
Changes in operating assets and liabilities:
Customer and other receivables	68			106
Materials, supplies and fossil fuel inventory	(22		)	(2		)
Other current assets	(18		)	(17		)
Other assets	(69		)	(10		)
Accounts payable and customer deposits	91			74
Income taxes	31			(66		)
Interest and other taxes	95			81
Other current liabilities	(94		)	(127		)
Other liabilities	27			(9		)
Net cash provided by operating activities	875			776
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(999		)	(810		)
Nuclear fuel purchases	(68		)	(11		)
Proceeds from sale or maturity of securities in special use funds	1,162			685
Purchases of securities in special use funds	(1,184		)	(701		)
Other - net	22			(1		)
Net cash used in investing activities	(1,067		)	(838		)
CASH FLOWS FROM FINANCING ACTIVITIES
Retirements of long-term debt	(29		)	(427		)
Net change in short-term debt	120			800
Capital contribution from NEE	100			—
Dividends to NEE	—			(340		)
Other - net	20			24
Net cash provided by financing activities	211			57
Net increase (decrease) in cash and cash equivalents	19			(5		)
Cash and cash equivalents at beginning of period	19			40
Cash and cash equivalents at end of period	$	38		$	35
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	$	317		$	339

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2013 Form 10-K.

12

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

The accompanying condensed consolidated financial statements should be read in conjunction with the 2013 Form 10-K.  In the opinion of NEE and FPL management, all adjustments (consisting of normal recurring accruals) considered necessary for fair financial statement presentation have been made.  Certain amounts included in the prior year's condensed consolidated financial statements have been reclassified to conform to the current year's presentation. See Note 3 - Nonrecurring Fair Value Measurements for a discussion of the decision not to pursue the sale of NEER's ownership interests in oil-fired generating plants located in Maine with a total generating capacity of 796 megawatts (MW) (Maine fossil) and the related financial statement impacts. The results of operations for an interim period generally will not give a true indication of results for the year.

1.  Employee Retirement Benefits

NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries and has a supplemental executive retirement plan, which includes a non-qualified supplemental defined benefit pension component that provides benefits to a select group of management and highly compensated employees (collectively, pension benefits).  In addition to pension benefits, NEE sponsors a contributory postretirement plan for health care and life insurance benefits (other benefits) for retirees of NEE and its subsidiaries meeting certain eligibility requirements.

The components of net periodic benefit (income) cost for the plans are as follows:

	Pension Benefits						Other Benefits
	Three Months Ended   March 31,						Three Months Ended   March 31,
	2014			2013			2014			2013
	(millions)
Service cost	$	16		$	18		$	1		$	1
Interest cost	25			24			4			4
Expected return on plan assets	(60		)	(60		)	—			—
Amortization of prior service cost (benefit)	1			2			(1		)	(1		)
Amortization of losses	—			1			—			1
Net periodic benefit (income) cost at NEE	$	(18	)	$	(15	)	$	4		$	5
Net periodic benefit (income) cost at FPL	$	(11	)	$	(10	)	$	3		$	3

2.  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 with outstanding and forecasted debt issuances, 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 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 the commodity price risk associated with the fuel requirements of the assets, where applicable, as well as 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 the 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.

13

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

Derivative instruments, when required to be marked to market, are recorded on NEE's and FPL's condensed 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 other - net in NEE's condensed consolidated statements of income.  Settlement gains and losses are included within the line items in the condensed 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 condensed 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 condensed consolidated statements of cash flows.

While most of NEE's derivatives are entered into for the purpose of managing commodity price risk, optimizing the value of NEER's power generation and gas infrastructure assets, reducing the impact of volatility in interest rates on outstanding and forecasted debt issuances and managing foreign currency risk, hedge accounting is only applied where specific criteria are met and it is practicable to do so.  In order to apply hedge accounting, the transaction must be designated as a hedge and it must be highly effective in offsetting the hedged risk.  Additionally, for hedges of forecasted transactions, the forecasted transactions must be probable.  For interest rate and foreign currency derivative instruments, generally NEE assesses a hedging instrument's effectiveness by using nonstatistical methods including dollar value comparisons of the change in the fair value of the derivative to the change in the fair value or cash flows of the hedged item.  Hedge effectiveness is tested at the inception of the hedge and on at least a quarterly basis throughout its life.  The effective portion of the gain or loss on a derivative instrument designated as a cash flow hedge is reported as a component of other comprehensive income (OCI) and is reclassified into earnings in the period(s) during which the transaction being hedged affects earnings or when it becomes probable that a forecasted transaction being hedged would not occur.  The ineffective portion of net unrealized gains (losses) on these hedges is reported in earnings in the current period.  In April 2013, NEE discontinued hedge accounting for cash flow hedges related to interest rate swaps associated with the solar projects in Spain (see Note 9 - Spain Solar Projects).  At March 31, 2014, NEE's accumulated other comprehensive income (AOCI) included amounts related to interest rate cash flow hedges with expiration dates through June 2031 and foreign currency cash flow hedges with expiration dates through September 2030.  Approximately $61 million of net losses included in AOCI at March 31, 2014 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 interest rates, currency exchange rates or scheduled principal payments.

14

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

Fair Value of Derivative Instruments - The tables below present NEE's and FPL's gross derivative positions at March 31, 2014 and December 31, 2013, 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 3 - Recurring Fair Value Measurements for netting information), as well as the location of the net derivative position on the condensed consolidated balance sheets.

	March 31, 2014
	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	$	—	$	—	$	4,553	$	3,705	$	1,441	$	834
Interest rate contracts	76		125		—		108		76		233
Foreign currency swaps	—		49		—		95		—		144
Total fair values	$	76	$	174	$	4,553	$	3,908	$	1,517	$	1,211
FPL:
Commodity contracts	$	—	$	—	$	123	$	3	$	130	$	10
Net fair value by NEE balance sheet line item:
Current derivative assets(a)									$	533
Noncurrent derivative assets(b)									984
Current derivative liabilities											$	815
Noncurrent derivative liabilities(c)											396
Total derivatives									$	1,517	$	1,211
Net fair value by FPL balance sheet line item:
Current other assets									$	129
Noncurrent other assets									1
Noncurrent other liabilities											$	10
Total derivatives									$	130	$	10

______________________

(a) Reflects the netting of approximately $165 million in margin cash collateral received from counterparties.

(b) Reflects the netting of approximately $88 million in margin cash collateral received from counterparties.

(c) Reflects the netting of approximately $12 million in margin cash collateral provided to counterparties.

15

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

	December 31, 2013
	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	$	—	$	—	$	4,543	$	3,633	$	1,571	$	940
Interest rate contracts	89		127		1		93		90		220
Foreign currency swaps	—		50		—		101		—		151
Total fair values	$	89	$	177	$	4,544	$	3,827	$	1,661	$	1,311
FPL:
Commodity contracts	$	—	$	—	$	55	$	9	$	48	$	2
Net fair value by NEE balance sheet line item:
Current derivative assets(a)									$	498
Noncurrent derivative assets(b)									1,163
Current derivative liabilities											$	838
Noncurrent derivative liabilities											473
Total derivatives									$	1,661	$	1,311
Net fair value by FPL balance sheet line item:
Current other assets									$	48
Current other liabilities											$	1
Noncurrent other liabilities											1
Total derivatives									$	48	$	2

______________________

(a) Reflects the netting of approximately $181 million in margin cash collateral received from counterparties.

(b) Reflects the netting of approximately $98 million in margin cash collateral received from counterparties.

At March 31, 2014 and December 31, 2013, NEE had approximately $45 million and $24 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 condensed consolidated balance sheets.  Additionally, at March 31, 2014 and December 31, 2013, NEE had approximately $109 million and $42 million (none at FPL), respectively, in margin cash collateral provided 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 condensed consolidated balance sheets.

Income Statement Impact of Derivative Instruments - Gains (losses) related to NEE's cash flow hedges are recorded in NEE's condensed consolidated financial statements (none at FPL) as follows:

	Three Months Ended March 31,
	2014											2013
	Interest Rate Contracts				Foreign Currency Swaps				Total			Interest Rate Contracts				Foreign Currency Swaps				Total
	(millions)
Gains (losses) recognized in OCI	$	(27	)		$	(2	)		$	(29	)	$	100			$	(8	)		$	92
Gains (losses) reclassified from AOCI to net income	$	(16	)	(a)	$	2		(b)	$	(14	)	$	(15	)	(a)	$	(19	)	(b)	$	(34	)

————————————

(a) Included in interest expense.

(b) Loss of approximately $1 million is included in interest expense and the balance is included in other - net.

For the three months ended March 31, 2014 and 2013, NEE recorded a gain of approximately $4 million and a loss of $9 million, respectively, on fair value hedges which resulted in a corresponding increase and decrease, respectively, in the related debt.

16

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

Gains (losses) related to NEE's derivatives not designated as hedging instruments are recorded in NEE's condensed consolidated statements of income as follows:

	Three Months Ended   March 31,
	2014			2013
	(millions)
Commodity contracts:(a)
Operating revenues	$	(272	)	$	(42	)
Fuel, purchased power and interchange	(4		)	3
Foreign currency swap - other - net	5			(32		)
Interest rate contracts - interest expense	(27		)	—
Total	$	(298	)	$	(71	)

————————————

(a) For the three months ended March 31, 2014 and 2013, FPL recorded approximately $136 million and $144 million of gains, respectively, related to commodity contracts as regulatory liabilities on its condensed 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 condensed 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:

	March 31, 2014					December 31, 2013
Commodity Type	NEE			FPL		NEE			FPL
	(millions)
Power	(111	)	MWh(a)	—		(276	)	MWh(a)	—
Natural gas	1,333		MMBtu(b)	937	MMBtu(b)	1,140		MMBtu(b)	674	MMBtu(b)
Oil	(9	)	barrels	—		(10	)	barrels	—

————————————

(a) Megawatt-hours

(b) One million British thermal units

At March 31, 2014 and December 31, 2013, NEE had interest rate contracts with a notional amount totaling approximately $6.8 billion and $6.5 billion, respectively, and foreign currency swaps with a notional amount totaling approximately $662 million and $662 million, respectively.

Credit-Risk-Related ContingentFeatures - 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 March 31, 2014 and December 31, 2013, the aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately $1.8 billion ($4 million for FPL) and $2.1 billion ($9 million for FPL), respectively.

If the credit-risk-related contingent features underlying these agreements and other commodity-related contracts 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 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 $300 million ($20 million at FPL) as of March 31, 2014 and $400 million ($20 million at FPL) as of December 31, 2013.If FPL's and NEECH's credit ratings were downgraded to below investment grade, applicable NEE subsidiaries would be required to post additional collateral such that the total posted collateral would be approximately $2.2 billion ($0.4 billion at FPL) and $2.3 billion ($0.4 billion at FPL) as of March 31, 2014 and December 31, 2013, respectively.  Some contracts do not contain credit ratings downgrade triggers, but do contain

17

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

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 $800 million ($200 million at FPL) and $800 million ($150 million at FPL) as of March 31, 2014 and December 31, 2013, respectively.

Collateral related to derivatives may be posted in the form of cash or credit support in the normal course of business.  At March 31, 2014 and December 31, 2013, applicable NEE subsidiaries have posted approximately $73 million (none at FPL) and $210 million (none at FPL), respectively, 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.

3.  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 their 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 - Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less.  NEE primarily holds investments in money market funds.  The fair value of these funds is calculated using current 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 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.

18

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

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 swaps to mitigate and adjust interest rate and foreign currency exposure related to certain outstanding and forecasted 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 a discounted cash flows valuation technique based on the net amount of estimated future cash inflows and outflows related to the agreements.

19

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

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:

	March 31, 2014
	Level 1		Level 2			Level 3		Netting(a)			Total
	(millions)
Assets:
Cash equivalents:
NEE - equity securities	$	84	$	—		$	—	$	—		$	84
Special use funds:(b)
NEE:
Equity securities	$	1,235	$	1,290	(c)	$	—	$	—		$	2,525
U.S. Government and municipal bonds	$	617	$	166		$	—	$	—		$	783
Corporate debt securities	$	—	$	612		$	—	$	—		$	612
Mortgage-backed securities	$	—	$	514		$	—	$	—		$	514
Other debt securities	$	25	$	44		$	—	$	—		$	69
FPL:
Equity securities	$	366	$	1,128	(c)	$	—	$	—		$	1,494
U.S. Government and municipal bonds	$	520	$	147		$	—	$	—		$	667
Corporate debt securities	$	—	$	427		$	—	$	—		$	427
Mortgage-backed securities	$	—	$	438		$	—	$	—		$	438
Other debt securities	$	25	$	25		$	—	$	—		$	50
Other investments:
NEE:
Equity securities	$	44	$	—		$	—	$	—		$	44
Debt securities	$	21	$	103		$	—	$	—		$	124
Derivatives:
NEE:
Commodity contracts	$	1,529	$	1,989		$	1,035	$	(3,112	)	$	1,441	(d)
Interest rate contracts	$	—	$	76		$	—	$	—		$	76	(d)
FPL - commodity contracts	$	—	$	119		$	4	$	7		$	130	(d)
Liabilities:
Derivatives:
NEE:
Commodity contracts	$	1,434	$	1,804		$	467	$	(2,871	)	$	834	(d)
Interest rate contracts	$	—	$	125		$	108	$	—		$	233	(d)
Foreign currency swaps	$	—	$	144		$	—	$	—		$	144	(d)
FPL - commodity contracts	$	—	$	2		$	1	$	7		$	10	(d)

————————————

(a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and 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 condensed consolidated balance sheets and are recorded in customer receivables - net and accounts payable, respectively.

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

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

(d) See Note 2 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's condensed consolidated balance sheets.

20

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

	December 31, 2013
	Level 1		Level 2			Level 3		Netting(a)			Total
	(millions)
Assets:
Cash equivalents:
NEE - equity securities	$	20	$	—		$	—	$	—		$	20
Special use funds:(b)
NEE:
Equity securities	$	1,170	$	1,336	(c)	$	—	$	—		$	2,506
U.S. Government and municipal bonds	$	647	$	180		$	—	$	—		$	827
Corporate debt securities	$	—	$	597		$	—	$	—		$	597
Mortgage-backed securities	$	—	$	479		$	—	$	—		$	479
Other debt securities	$	16	$	44		$	—	$	—		$	60
FPL:
Equity securities	$	291	$	1,176	(c)	$	—	$	—		$	1,467
U.S. Government and municipal bonds	$	584	$	154		$	—	$	—		$	738
Corporate debt securities	$	—	$	421		$	—	$	—		$	421
Mortgage-backed securities	$	—	$	401		$	—	$	—		$	401
Other debt securities	$	16	$	30		$	—	$	—		$	46
Other investments:
NEE:
Equity securities	$	51	$	—		$	—	$	—		$	51
Debt securities	$	11	$	107		$	—	$	—		$	118
Derivatives:
NEE:
Commodity contracts	$	1,368	$	2,106		$	1,069	$	(2,972	)	$	1,571	(d)
Interest rate contracts	$	—	$	90		$	—	$	—		$	90	(d)
FPL - commodity contracts	$	—	$	53		$	2	$	(7	)	$	48	(d)
Liabilities:
Derivatives:
NEE:
Commodity contracts	$	1,285	$	1,994		$	354	$	(2,693	)	$	940	(d)
Interest rate contracts	$	—	$	127		$	93	$	—		$	220	(d)
Foreign currency swaps	$	—	$	151		$	—	$	—		$	151	(d)
FPL - commodity contracts	$	—	$	7		$	2	$	(7	)	$	2	(d)

————————————

(a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and 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 condensed consolidated balance sheets and are recorded in customer receivables - net and accounts payable, respectively.

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

(c) At NEE, approximately $1,300 million ($1,141 million at FPL) are invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

(d) See Note 2 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's condensed 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,

21

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

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 critically 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 March 31, 2014 are as follows:

Transaction Type	Fair Value at March 31, 2014				Valuation Technique(s)	Significant Unobservable Inputs	Range
	Assets		Liabilities
	(millions)
Forward contracts - power	$	605	$	106	Discounted cash flow	Forward price (per MWh)	$9	—	$156
Forward contracts - gas	96		44		Discounted cash flow	Forward price (per MMBtu)	$2	—	$16
Forward contracts - other commodity related	23		16		Discounted cash flow	Forward price (various)	$1	—	$245
Options - power	79		84		Option models	Implied correlations	7%	—	96%
						Implied volatilities	1%	—	271%
Options - gas	34		57		Option models	Implied correlations	7%	—	96%
						Implied volatilities	1%	—	70%
Full requirements and unit contingent contracts	198		160		Discounted cash flow	Forward price (per MWh)	$(10)	—	$203
						Customer migration rate(a)	—%	—	20%
Total	$	1,035	$	467

——————————

(a) Applies only to full requirements contracts.

22

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

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 swap liabilities related to the solar projects in Spain of approximately $108 million at March 31, 2014 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 swap agreements.

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

	Three Months Ended March 31,
	2014						2013
	NEE			FPL			NEE			FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at December 31	$	622		$	—		$	566		$	2
Realized and unrealized gains (losses):
Included in earnings(a)	(423		)	—			(3		)	—
Included in regulatory assets and liabilities	4			4			1			1
Purchases	4			—			49			—
Settlements	266			(1		)	(33		)	(1		)
Issuances	(19		)	—			(64		)	—
Transfers in(b)	7			—			—			—
Transfers out(b)	(1		)	—			6			—
Fair value of net derivatives based on significant unobservable inputs at March 31	$	460		$	3		$	522		$	2
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)	$	(249	)	$	—		$	32		$	—

————————————

(a) For the three months ended March 31, 2014, realized and unrealized losses of approximately $405 million are reflected in the condensed consolidated statements of income in operating revenues, $15 million in interest expense and the balance is reflected in fuel, purchased power and interchange.  For the three months ended March 31, 2013, realized and unrealized losses are reflected in the condensed consolidated statements of income in fuel, purchased power and interchange.

(b) Transfers into Level 3 were a result of decreased observability of market data and transfers from Level 3 to Level 2 were a result of increased observability of market data.  NEE's and FPL's policy is to recognize all transfers at the beginning of the reporting period.

(c) For the three months ended March 31, 2014, unrealized losses of $234 million are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in interest expense.  For the three months ended March 31, 2013, unrealized gains of approximately $31 million are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

Nonrecurring Fair Value Measurements - NEE tests long-lived assets for recoverability whenever events or changes in circumstances indicate that the carrying amount may not be recoverable.  In February 2013, the Spanish government enacted a new law that made further changes to the economic framework of renewable energy projects including, among other things, changes that negatively affect the projected economics of the 99.8 MW of solar thermal facilities that affiliates of NEER were constructing in Spain (Spain solar projects) (see Note 9 - Spain Solar Projects).  Due to the February 2013 change in law, NEER performed a recoverability analysis, considering, among other things, working with lenders to restructure the financing agreements, abandoning the projects or selling the projects, and concluded that the undiscounted cash flows of the Spain solar projects were less than the

23

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

carrying value of the projects.  Accordingly, NEER performed a fair value analysis based on the income approach to determine the amount of the impairment.  Based on the fair value analysis, property, plant and equipment with a carrying amount of approximately $800 million were written down to their estimated fair value of approximately $500 million as of March 31, 2013, resulting in an impairment of $300 million (which is recorded as a separate line item in NEE’s condensed consolidated statements of income for the three months ended March 31, 2013) and other related charges ($342 million after-tax, see Note 4).

The estimate of the fair value was based on the discounted cash flows which were determined using a market participant view of the Spain solar projects upon completion and final commissioning of the projects.  As part of the valuation, NEER used observable inputs where available, including the revised renewable energy pricing under the February 2013 change in law.  Significant unobservable inputs (Level 3), including forecasts of generation, estimates of tariff escalation rates and estimated costs of debt and equity capital, were also used in the estimation of fair value.  In addition, NEER made certain assumptions regarding the projected capital and maintenance expenditures based on the estimated costs to complete the Spain solar projects and ongoing capital and maintenance expenditures.  An increase in the revenue and generation forecasts, a decrease in the projected capital and maintenance expenditures or a decrease in the weighted-average cost of capital each would result in an increased fair market value.  Changes in the opposite direction of those unobservable inputs would result in a decreased fair market value.  See Note 9 - Spain Solar Projects for a discussion of additional developments that could potentially impact the Spain solar projects.

In March 2013, NEER initiated a plan and received internal authorization to pursue the sale of its ownership interests in Maine fossil.  In connection with the decision to sell Maine fossil, a loss of approximately $67 million ($43 million after-tax) was originally reflected in net gain from discontinued operations, net of income taxes in NEE's condensed consolidated statements of income for the three months ended March 31, 2013.  The fair value measurement (Level 3) was based on the estimated sales price less the estimated costs to sell.  The estimated sales price was estimated using an income approach based primarily on capacity revenue forecasts.  In March 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). The fair value measurement (Level 3) was estimated using an income approach based primarily on the updated capacity revenue forecasts. Based on NEER's decision to retain Maine fossil, the $67 million loss recorded during the three months ended March 31, 2013 was reclassified from discontinued operations to income from continuing operations and together with the $21 million gain recorded during the three months ended March 31, 2014 are included as a separate line item in NEE's condensed consolidated statements of income. The carrying amount of the assets and liabilities and the operations of Maine fossil for all periods presented were not material.

Fair Value of Financial Instruments Recorded at the Carrying Amount - The carrying amounts of cash equivalents, short-term debt and commercial paper approximate their fair values.  The carrying amounts and estimated fair values of other financial instruments, excluding those recorded at fair value and disclosed above in Recurring Fair Value Measurements, are as follows:

	March 31, 2014					December 31, 2013
	Carrying Amount		Estimated Fair Value			Carrying Amount		Estimated Fair Value
	(millions)
NEE:
Special use funds(a)	$	363	$	363		$	311	$	311
Other investments - primarily notes receivable	$	528	$	667	(b)	$	531	$	627	(b)
Long-term debt, including current maturities	$	27,639	$	28,782	(c)	$	27,728	$	28,612	(c)
FPL:
Special use funds(a)	$	251	$	251		$	200	$	200
Long-term debt, including current maturities	$	8,801	$	9,384	(c)	$	8,829	$	9,451	(c)

————————————

(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 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.  As of March 31, 2014 and December 31, 2013, NEE had no notes receivable reported in non-accrual status.

(c) As of March 31, 2014 and December 31, 2013, for NEE, $18,135 million and $17,921 million, respectively, is estimated using quoted market prices for the same or similar issues (Level 2); the balance is estimated using a discounted cash flow valuation technique, considering the current credit spread of the debtor (Level 3).  For FPL, 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) consist of FPL's storm fund assets of $75 million and NEE's and FPL's nuclear decommissioning fund assets of $4,791 million and $3,252 million, respectively, at March 31, 2014.  The investments held in the special use funds consist of equity and debt securities

24

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

which are primarily classified as available for sale and carried at estimated fair value.  The amortized cost of debt and equity securities is $1,941 million and $1,420 million, respectively, at March 31, 2014 and $1,954 million and $1,384 million, respectively, at December 31, 2013 ($1,550 million and $714 million, respectively, at March 31, 2014 and $1,595 million and $694 million, respectively, at December 31, 2013 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 and included in other - net in NEE's condensed consolidated statements of income.  Debt securities included in the nuclear decommissioning funds have a weighted-average maturity at March 31, 2014 of approximately six years at both NEE and FPL.  FPL's storm fund primarily consists of debt securities with a weighted-average maturity at March 31, 2014 of approximately three years.  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
	Three Months Ended   March 31,				Three Months Ended   March 31,
	2014		2013		2014		2013
	(millions)
Realized gains	$	77	$	42	$	32	$	23
Realized losses	$	22	$	30	$	17	$	22
Proceeds from sale or maturity of securities	$	1,401	$	924	$	1,162	$	685

The unrealized gains on available for sale securities are as follows:

	NEE				FPL
	March 31, 2014		December 31, 2013		March 31, 2014		December 31, 2013
	(millions)
Equity securities	$	1,105	$	1,125	$	780	$	777
Debt securities	$	49	$	42	$	41	$	36

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
	March 31, 2014		December 31, 2013		March 31, 2014		December 31, 2013
	(millions)
Unrealized losses(a)	$	12	$	32	$	10	$	25
Fair value	$	660	$	1,069	$	516	$	844

————————————

(a) Unrealized losses on available for sale debt securities for securities in an unrealized loss position for greater than twelve months at March 31, 2014 and December 31, 2013 were not material to NEE or FPL.

Regulations issued by the Federal Energy Regulatory Commission (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 NEER's Seabrook Station (Seabrook), decommissioning fund contributions and withdrawals are also regulated by the Nuclear Decommissioning Financing Committee pursuant to New Hampshire law.

25

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

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.

4.  Income Taxes

NEE's effective income tax rates for the three months ended March 31, 2014 and 2013 were approximately 26% and 78%, respectively.  The rate for the three months ended March 31, 2013 reflects the establishment of a full valuation allowance of approximately $132 million on the deferred tax assets associated with the Spain solar projects.  This valuation allowance primarily related to deferred tax assets created as a result of the $300 million impairment and other related charges ($342 million after-tax) recorded for the three months ended March 31, 2013 (see Note 3 - Nonrecurring Fair Value Measurements).  In addition, the rates for both periods reflect the benefit of wind production tax credits (PTCs) of approximately $49 million and $59 million, respectively, related to NEER's wind projects and deferred income tax benefits associated with grants (convertible investment tax credits (ITCs)) under the American Recovery and Reinvestment Act of 2009, as amended (Recovery Act), of approximately $12 million and $13 million, respectively, primarily for certain wind and solar projects expected to be placed in service.

NEE recognizes PTCs as wind energy is generated and sold based on a per kilowatt-hour (kWh) rate prescribed in applicable federal and state statutes, which may differ significantly from amounts computed, on a quarterly basis, using an overall effective income tax rate anticipated for the full year.  NEE uses this method of recognizing PTCs for specific reasons, including that PTCs are an integral part of the financial viability of most wind projects and a fundamental component of such wind projects' results of operations.  PTCs, as well as deferred income tax benefits associated with convertible ITCs, can significantly affect NEE's effective income tax rate depending on the amount of pretax income.  The amount of PTCs recognized can be significantly affected by wind generation and by the roll off of PTCs after ten years of production (PTC roll off).

5.  Discontinued Operations

In March 2013, a subsidiary of NEER completed the sale of its ownership interest in a portfolio of hydropower generation plants and related assets (hydro sale) with a total generating capacity of 351 MW located in Maine and New Hampshire.  The sales price primarily included the assumption by the buyer of $700 million in related debt.In connection with the sale, a gain of approximately $372 million ($231 million after-tax) is reflected in gain from discontinued operations, net of income taxes in NEE's condensed consolidated statements of income for the three months ended March 31, 2013.  The operations of the hydropower generation plants, exclusive of the gain, were not material to NEE's condensed consolidated statements of income for the three months ended March 31, 2013.

See Note 3 - Nonrecurring Fair Value Measurements for a discussion of the decision not to pursue the sale of Maine fossil and the related financial statement impacts.

6.  Variable Interest Entities (VIEs)

As of March 31, 2014, NEE has fourteen 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 $290 million and $324 million at March 31, 2014 and December 31, 2013, respectively, and consisted primarily of storm-recovery property, which are included in securitized storm-recovery costs on NEE's and FPL's condensed consolidated balance sheets.  The liabilities of the VIE were approximately $360 million and $394 million at March 31, 2014 and December 31, 2013, respectively, and consisted primarily of storm-recovery bonds, which are included in long-term debt on NEE's and FPL's condensed consolidated balance sheets.

26

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

FPL identified a potential VIE, which is considered a qualifying facility as defined by the Public Utility Regulatory Policies Act of 1978, as amended (PURPA).  PURPA requires utilities, such as FPL, to purchase the electricity output of a qualifying facility.  FPL entered into a purchased power agreement effective in 1994 with this 250 MW coal-fired qualifying facility to purchase substantially all of the facility's capacity and electrical output over a substantial portion of its estimated useful life.  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).  After making exhaustive efforts, FPL was unable to obtain the information from the facility necessary to determine whether the facility is a VIE or whether FPL is the primary beneficiary of the facility.  The purchased power agreement with the facility contains no provision which legally obligates the facility to release this information to FPL.  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.  Notwithstanding the fact that FPL's energy payments are recovered through the fuel clause, if the facility was determined to be a VIE, the absorption of some of the facility's fuel price variability might cause FPL to be considered the primary beneficiary.  During the three months ended March 31, 2014 and 2013, FPL purchased 128,940 MWh and 79,210 MWh, respectively, from the facility at a total cost of approximately $36 million and $35 million, respectively.

Additionally, FPL entered into a purchased power agreement effective in 1995 with a 330 MW coal-fired qualifying facility to purchase substantially all of the facility's 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 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.

NEER - NEE consolidates thirteen 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, and through its 100% equity ownership has the obligation to absorb expected losses of these VIEs.

A NEER VIE consolidates two entities which own and operate natural gas/oil electric generating facilities with the capability of producing 110 MW.  This VIE sells its 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.  This VIE uses third-party debt and equity to finance its operations.  The debt is secured by liens against the generating 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 $90 million and $65 million, respectively, at March 31, 2014 and $85 million and $63 million, respectively, at December 31, 2013, and consisted primarily of property, plant and equipment and long-term debt.

The other twelve NEER VIEs consolidate several entities which own and operate wind electric generating facilities with the capability of producing a total of 3,541 MW.  Ten of these VIEs sell their electric output under power sales contracts to third parties with expiration dates ranging from 2018 through 2038; the other two VIEs sell their electric output in the spot market.  The VIEs use third-party debt and/or equity to finance their operations.  Certain investors that hold no equity interest in the VIEs hold differential membership interests, which give them the right to receive a portion of the economic attributes of the generating facilities, including certain tax attributes.  The debt is secured by liens against the generating 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 $5.2 billion and $3.3 billion, respectively, at March 31, 2014 and $5.3 billion and $3.3 billion, respectively, at December 31, 2013.  At March 31, 2014 and December 31, 2013, 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 March 31, 2014 and December 31, 2013, several NEE subsidiaries have investments totaling approximately $700 million ($541 million at FPL) and $668 million ($505 million at FPL), respectively, in certain special purpose entities, which consisted primarily of investments in mortgage-backed securities.  These investments are included in special use funds and other investments on NEE's condensed consolidated balance sheets and in special use funds on FPL's condensed consolidated balance sheets.  As of March 31, 2014, NEE subsidiaries 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.

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(unaudited)

7.  Common Shareholders' Equity

Earnings Per Share - The reconciliation of NEE's basic and diluted earnings per share of common stock from continuing operations is as follows:

	Three Months Ended   March 31,
	2014		2013
	(millions, except per share amounts)
Numerator - income from continuing operations	$	430	$	41
Denominator:
Weighted-average number of common shares outstanding - basic	433.5		421.0
Performance share awards, equity units, options, forward sale agreement and restricted stock(a)	4.7		2.7
Weighted-average number of common shares outstanding - assuming dilution	438.2		423.7
Earnings per share of common stock from continuing operations:
Basic	$	0.99	$	0.10
Assuming dilution	$	0.98	$	0.10

————————————

(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 stock options and performance shares awards and restricted stock which were not included in the denominator above due to their antidilutive effect were approximately 0.1 million and 0.4 million for the three months ended March 31, 2014 and 2013, respectively.

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

	Accumulated Other Comprehensive Income (Loss)
	Net Unrealized Gains (Losses) on Cash Flow Hedges				Net Unrealized Gains (Losses) on Available for Sale Securities				Defined Benefit Pension and Other Benefits Plans		Net Unrealized Gains (Losses) on Foreign Currency Translation			Other Comprehensive Income (Loss) Related to Equity Method Investee			Total
	(millions)
Balances, December 31, 2013	$	(115	)		$	197			$	23	$	(33	)	$	(16	)	$	56
Other comprehensive income (loss) before reclassifications	(18		)		13				4		(17		)	(2		)	(20		)
Amounts reclassified from AOCI	9			(a)	(25		)	(b)	1		—			—			(15		)
Net other comprehensive income (loss)	(9		)		(12		)		5		(17		)	(2		)	(35		)
Balances, March 31, 2014	$	(124	)		$	185			$	28	$	(50	)	$	(18	)	$	21

————————————

(a) Reclassified to interest expense and other - net in NEE's condensed consolidated statements of income.  See Note 2 - Income Statement Impact of Derivative Instruments.

(b) Reclassified to gains on disposal of assets - net in NEE's condensed consolidated statements of income.

	Accumulated Other Comprehensive Income (Loss)
	Net Unrealized Gains (Losses) on Cash Flow Hedges				Net Unrealized Gains (Losses) on Available for Sale Securities				Defined Benefit Pension and Other Benefits Plans			Net Unrealized Gains (Losses) on Foreign Currency Translation			Other Comprehensive Income (Loss) Related to Equity Method Investee			Total
	(millions)
Balances, December 31, 2012	$	(266	)		$	96			$	(74	)	$	12		$	(23	)	$	(255	)
Other comprehensive income (loss) before reclassifications	65				40				6			(9		)	1			103
Amounts reclassified from AOCI	21			(a)	(6		)	(b)	1			—			—			16
Net other comprehensive income (loss)	86				34				7			(9		)	1			119
Balances, March 31, 2013	$	(180	)		$	130			$	(67	)	$	3		$	(22	)	$	(136	)

————————————

(a) Reclassified to interest expense and other - net in NEE's condensed consolidated statements of income. See Note 2 - Income Statement Impact of Derivative Instruments.

(b) Reclassified to gains on disposal of assets - net in NEE's condensed consolidated statements of income.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

8.  Debt

Significant long-term debt issuances and borrowings by subsidiaries of NEE during the three months ended March 31, 2014 were as follows:

Date Issued	Company	Debt Issuances/Borrowings	Interest Rate			Principal Amount		Maturity Date
						(millions)
January - March 2014	NEER subsidiary	Canadian revolving credit agreements	Variable		(a)	$	245	Various
January 2014	NEER subsidiary	Senior secured limited-recourse term loan	Variable		(a)	$	44	2019
March 2014	NEECH	Debentures	2.700	%	(b)	$	350	2019

————————————

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

(b) An interest rate swap agreement has been entered into with respect to this issuance.  See Note 2.

9.  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.  Capital expenditures for Corporate and Other primarily include the cost for construction of a natural gas pipeline system for new natural gas transportation infrastructure in Florida, as well as the cost to meet customer-specific requirements and maintain the fiber-optic network for the fiber-optic telecommunications business (FPL FiberNet) and the cost to maintain existing transmission facilities at NextEra Energy Transmission, LLC (NEET).

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

At March 31, 2014, estimated capital expenditures for the remainder of 2014 through 2018 were as follows:

	Remainder of 2014		2015		2016		2017		2018		Total
	(millions)
FPL:
Generation:(a)
New(b)(c)	$	475	$	295	$	70	$	—	$	—	$	840
Existing	565		680		610		580		545		2,980
Transmission and distribution	1,055		1,200		1,125		955		1,025		5,360
Nuclear fuel	80		210		220		190		180		880
General and other	130		155		120		165		160		730
Total(d)	$	2,305	$	2,540	$	2,145	$	1,890	$	1,910	$	10,790
NEER:
Wind(e)	$	1,505	$	610	$	25	$	10	$	15	$	2,165
Solar(f)	480		750		520		—		—		1,750
Nuclear(g)	265		275		295		255		265		1,355
Other(h)	345		20		75		40		75		555
Total	$	2,595	$	1,655	$	915	$	305	$	355	$	5,825
Corporate and Other(i)	$	190	$	445	$	795	$	225	$	95	$	1,750

————————————

(a) Includes allowance for funds used during construction (AFUDC) of approximately $28 million, $53 million and $17 million for the remainder of 2014 through 2016, respectively.

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

(c) Consists of projects that have received FPSC approval. Excludes capital expenditures for the construction costs for the two additional nuclear units at FPL's Turkey Point site beyond what is required to receive an NRC license for each unit.

(d) FPL has identified $1.5 billion to $2.5 billion in potential incremental capital expenditures through 2016 in addition to what is included in the table above.

(e) Consists of capital expenditures for new wind projects and related transmission totaling approximately 1,815 MW, including approximately 465 MW in Canada, that have received applicable internal approvals.  NEER expects to add new U.S. wind generation of 2,000 MW to 2,500 MW in 2013 through 2015, including 325 MW added to date, at a total cost of up to $3.5 billion to $4.5 billion.

(f) Consists of capital expenditures for new solar projects and related transmission totaling approximately 600 MW that have received applicable internal approvals, including equity contributions associated with a 50% equity investment in a 550 MW solar project.  Includes approximately $1 billion of total estimated costs associated with the pending acquisition of the development rights for a 250 MW solar project that is expected to close in mid-2014, subject to certain conditions precedent, and construction of the project, which is expected to be completed in 2016.  Excludes solar projects requiring internal approvals with generation totaling 47 MW with an estimated cost of approximately $120 million.

(g) Includes nuclear fuel.

(h) Consists of capital expenditures that have received applicable internal approvals.

(i) Includes capital expenditures totaling approximately $1.4 billion for the remainder of 2014 through 2018 for construction of a natural gas pipeline system that has received applicable internal approvals, including approximately $885 million of equity contributions associated with a 33% equity investment in the northern portion of the natural gas pipeline system and $525 million for the southern portion, which includes AFUDC of approximately $1 million, $7 million, $20 million and $12 million for the remainder of 2014 through 2017, respectively.  The natural gas pipeline system is subject to certain conditions, including FERC approval.  A FERC decision is expected in 2015. 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 March 31, 2014, FPL is obligated under take-or-pay purchased power contracts with JEA and with subsidiaries of The Southern Company (Southern subsidiaries) to pay for approximately 1,330 MW annually through 2015 and 375 MW annually thereafter through 2021.  FPL also has various firm pay-for-performance contracts to purchase approximately 705 MW from certain cogenerators and small power producers (qualifying facilities) with expiration dates ranging from 2024 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 qualifying 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 NEECH subsidiary has a 33% ownership interest), and Florida Southeast Connection, LLC (Florida Southeast Connection, a wholly-owned NEECH 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 on May 1, 2017 and increasing to 600,000 MMBtu/day on May 1, 2020.  These agreements contain firm commitments that are contingent upon the occurrence of certain events, including FERC approval and completion of construction of the pipeline to be built by each of Sabal Trail and Florida Southeast Connection.  See Commitments above.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

As of March 31, 2014, NEER has entered into contracts with expiration dates ranging from June 2014 through 2030 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, conversion, enrichment and fabrication of nuclear fuel.  Approximately $2.4 billion of commitments under such contracts 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 and firm transmission service with expiration dates ranging from October 2014 through 2033.

Included in Corporate and Other in the table below is the remaining commitment by a NEECH subsidiary to invest over $900 million in Sabal Trail for the construction of the northern portion of the natural gas pipeline system.  Amounts committed for the remainder of 2014 through 2018 are also included in the estimated capital expenditures table in Commitments above.

The required capacity and/or minimum payments under the contracts discussed above as of March 31, 2014 were estimated as follows:

	Remainder of 2014		2015		2016		2017		2018		Thereafter
	(millions)
FPL:
Capacity charges:(a)
Qualifying facilities	$	210	$	290	$	250	$	255	$	260	$	1,965
JEA and Southern subsidiaries	$	165	$	195	$	70	$	50	$	10	$	5
Minimum charges, at projected prices:(b)
Natural gas, including transportation and storage(c)	$	1,485	$	855	$	685	$	745	$	825	$	14,520
Coal	$	50	$	40	$	20	$	—	$	—	$	—
NEER	$	1,590	$	600	$	175	$	105	$	105	$	475
Corporate and Other(d)(e)	$	130	$	250	$	515	$	50	$	25	$	50

————————————

(a) Capacity charges under these contracts, substantially all of which are recoverable through the capacity cost recovery clause, totaled approximately $123 million and $126 million for the three months ended March 31, 2014 and 2013, respectively.  Energy charges under these contracts, which are recoverable through the fuel clause, totaled approximately $56 million and $23 million for the three months ended March 31, 2014 and 2013, respectively.

(b) Recoverable through the fuel clause.

(c) Includes approximately $200 million, $295 million and $8,535 million in 2017, 2018 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 $50 million commitment to invest in clean power and technology businesses through 2021.

(e) Excludes approximately $320 million and $200 million in 2014 and 2015, respectively, of joint obligations of NEECH and NEER which are included in the NEER amounts above.

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 $375 million of private liability insurance per site, which is the maximum obtainable, and participates in a secondary financial protection system, which provides up to $13.2 billion of liability insurance coverage per incident at any nuclear reactor in the United States.  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 United States, 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 Energy Center (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 $175 million ($106 million for FPL), plus any applicable taxes, in retrospective premiums in a policy year.  NEE and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook, Duane Arnold and St. Lucie Unit No. 2, which approximates $2 million, $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 its transmission and distribution property and has no property insurance coverage for FPL FiberNet's fiber-optic cable.  Should FPL's future storm restoration costs exceed the reserve amount established through the issuance of storm-

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

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

Spain Solar Projects - On March 28, 2013 and May 3, 2013, events of default occurred under the project-level financing agreements for the Spain solar projects (project-level financing) as a result of changes of law that occurred in December 2012 and February 2013.  These changes of law negatively affected the projected economics of the projects and have caused the project-level financing to be unsupportable by expected future project cash flows.  Under the project-level financing, events of default provide for, among other things, a right by the lenders (which they did not exercise for the project-level financing) to accelerate the payment of the project-level debt.  Accordingly, in 2013, the project-level debt and the associated derivative liabilities related to interest rate swaps were classified as current maturities of long-term debt and current derivative liabilities, respectively, with balances of $792 million and $108 million, respectively, on NEE's condensed consolidated balance sheets as of March 31, 2014. In July 2013, the Spanish government published a new law that created a new economic framework for the Spanish renewable energy sector.  Additional regulatory pronouncements from the Spanish government are needed to complete and implement the framework.  In February 2014, a draft of the regulatory pronouncements was made public. It is uncertain when the final regulatory pronouncements will be issued. At this time, NEE is unable to assess the framework's ultimate impact on the Spain solar projects which could include further impairment of the Spain solar projects and/or a partial refund of tariff revenues collected since July 2013.

As part of a settlement agreement reached on December 20, 2013 between NEECH, NextEra Energy España, S.L. (NEE España), which is the NEER subsidiary in Spain that is the direct shareholder of the project-level subsidiaries, the project-level subsidiaries and the lenders, the future recourse of the lenders under the project-level financing agreements is effectively limited to the letters of credit described below and to the assets of NEE España and the project-level subsidiaries. Under the settlement agreement, the lenders, among other things, irrevocably waived events of default related to changes of law, including those described above, and agreed not to exercise any rights with respect to any additional events of default that may occur with respect to implementing existing changes of law between the settlement date through June 1, 2014 and NEECH affiliates provided for the project-level subsidiaries to post approximately €37 million (approximately $51 million as of March 31, 2014) in letters of credit to fund operating and debt service reserves under the project-level financing agreements and €10 million (approximately $14 million as of March 31, 2014) in a letter of credit to provide support for a performance guarantee under the project-level financing agreements.  Additionally, NEE España, the project-level subsidiaries and the lenders have agreed to use commercially reasonable efforts to seek to restructure the project-level financing on or before June 1, 2014.  There can be no assurance that the project-level financing will be successfully restructured.

Legal Proceedings - In November 1999, the Attorney General of the United States, on behalf of the U.S. Environmental Protection Agency (EPA), brought an action in the U.S. District Court for the Northern District of Georgia against Georgia Power Company and other subsidiaries of The Southern Company for certain alleged violations of the Prevention of Significant Deterioration (PSD) provisions and the New Source Performance Standards (NSPS) of the Clean Air Act.  In May 2001, the EPA amended its complaint to allege, among other things, that Georgia Power Company constructed and is continuing to operate Scherer Unit No. 4, in which FPL owns an interest of approximately 76%, without obtaining a PSD permit, without complying with NSPS requirements, and without applying best available control technology for nitrogen oxides, sulfur dioxides and particulate matter as required by the Clean Air Act.  It also alleges that unspecified major modifications have been made at Scherer Unit No. 4 that require its compliance with the aforementioned Clean Air Act provisions.  The EPA seeks injunctive relief requiring the installation of best available control technology and civil penalties.  Under the EPA's civil penalty rules, the EPA could assess up to $25,000 per day for each violation from an unspecified date after June 1, 1975 through January 30, 1997, up to $27,500 per day for each violation from January 31, 1997 through March 15, 2004, up to $32,500 per day for each violation from March 16, 2004 through January 12, 2009 and up to $37,500 per day for each violation thereafter.  Georgia Power Company has answered the amended complaint, asserting that it has complied with all requirements of the Clean Air Act, denying the plaintiff's allegations of liability, denying that the plaintiff is entitled to any of the relief that it seeks and raising various other defenses.  In June 2001, a federal district court stayed discovery and administratively closed the case and the EPA has not yet moved to reopen the case.  In April 2007, the U.S. Supreme Court in a separate unrelated case rejected an argument that a "major modification" occurs at a plant only when there is a resulting increase in the hourly rate of air emissions.  Georgia Power Company has made a similar argument in defense of its case, but has other factual and legal defenses that are unaffected by the U.S. Supreme Court's decision.

In 1995 and 1996, NEE, through an indirect subsidiary, purchased from Adelphia Communications Corporation (Adelphia) 1,091,524 shares of Adelphia common stock and 20,000 shares of Adelphia preferred stock (convertible into 2,358,490 shares of Adelphia common stock) for an aggregate price of approximately $35,900,000.  On January 29, 1999, Adelphia repurchased all of these shares for $149,213,130 in cash.  In June 2004, Adelphia, Adelphia Cablevision, L.L.C. and the Official Committee of Unsecured Creditors of Adelphia filed a complaint against NEE and its indirect subsidiary in the U.S. Bankruptcy Court, Southern District of

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

New York.  The complaint alleges that the repurchase of these shares by Adelphia was a fraudulent transfer, in that at the time of the transaction Adelphia (i) was insolvent or was rendered insolvent, (ii) did not receive reasonably equivalent value in exchange for the cash it paid, and (iii) was engaged or about to engage in a business or transaction for which any property remaining with Adelphia had unreasonably small capital.  The complaint seeks the recovery for the benefit of Adelphia's bankruptcy estate of the cash paid for the repurchased shares, plus interest from January 29, 1999.  NEE has filed an answer to the complaint.  NEE believes that the complaint is without merit because, among other reasons, Adelphia will be unable to demonstrate that (i) Adelphia's repurchase of shares from NEE, which repurchase was at the market value for those shares, was not for reasonably equivalent value, (ii) Adelphia was insolvent at the time of the repurchase, or (iii) the repurchase left Adelphia with unreasonably small capital.  The trial was completed in May 2012 and closing arguments were heard in July 2012.

In 2004, TXU Portfolio Management Company (TXU) served several NEER affiliates as defendants in a civil action filed in the District Court in Dallas County, Texas.  The petition alleged that the NEER affiliates had contractual obligations to produce and sell to TXU a minimum quantity of energy and renewable energy credits each year during the period from 2002 through 2005 and that the NEER affiliates failed to meet this obligation.  TXU asserted claims for breach of contract and declaratory judgment and sought damages of approximately $34 million plus attorneys' fees, costs and interest.  Following a jury trial in 2007, the trial court issued a final judgment holding that the contracts were not terminated and neither party was entitled to recover any damages, which judgment was appealed by TXU.  In 2010, the appellate court reversed portions of the trial court's judgment, ruling that the contracts' liquidated damage provision is an enforceable liquidated damages clause.  In 2011, the NEER affiliates filed a petition for review of the appellate court decision with the Texas Supreme Court. In March 2014, the Texas Supreme Court, among other things, reversed the appellate court decision by ruling that the liquidated damages clause was an unenforceable penalty.

NEE and FPL are vigorously defending, and believe that they or their affiliates have meritorious defenses to, the lawsuits described above.  In addition to the legal proceedings discussed above, NEE and its subsidiaries, including FPL, are involved in other legal and regulatory proceedings, actions and claims in the ordinary course of their businesses.  Generating plants in which subsidiaries of NEE, including FPL, have an ownership interest are also involved in legal and regulatory proceedings, actions and claims, the liabilities from which, if any, would be shared by such subsidiary.  In the event that NEE and FPL, or their affiliates, do not prevail in the lawsuits described above or these other legal and regulatory proceedings, actions and claims, there may be a material adverse effect on their financial statements.  While management is unable to predict with certainty the outcome of the lawsuits described above or these other legal and regulatory proceedings, actions and claims, based on current knowledge it is not expected that their ultimate resolution, individually or collectively, will have a material adverse effect on the financial statements of NEE or FPL.

10.  Segment Information

NEE's reportable segments are FPL, a rate-regulated electric utility, and NEER, a competitive energy business.  NEER's segment information includes an allocation of interest expense from NEECH based on a deemed capital structure of 70% debt and allocated shared service costs.  Corporate and Other represents other business activities, other segments that are not separately reportable and eliminating entries.  NEE's segment information is as follows:

	Three Months Ended March 31,
	2014										2013
	FPL		NEER(a)			Corporate and Other			NEE Consoli- dated		FPL		NEER(a)				Corporate and Other		NEE Consoli- dated
									(millions)
Operating revenues	$	2,535	$	1,034		$	105		$	3,674	$	2,188	$	1,016			$	75	$	3,279
Operating expenses	$	1,903	$	952		$	81		$	2,936	$	1,645	$	1,149		(b)	$	51	$	2,845
Income (loss) from continuing operations(c)	$	347	$	86	(d)	$	(3	)	$	430	$	288	$	(256	)	(d)	$	9	$	41
Gain from discontinued operations, net of income taxes(c)(e)	$	—	$	—		$	—		$	—	$	—	$	216			$	15	$	231
Net income (loss)	$	347	$	86	(d)	$	(3	)	$	430	$	288	$	(40	)	(d)	$	24	$	272

————————————

(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 non-utility interest expense is included in Corporate and Other.

(b) Includes an impairment charge on NEER's Spain solar projects of $300 million.  See Note 3 - Nonrecurring Fair Value Measurements.

(c) Prior year amounts were restated to conform to current year's presentation.  See Note 3 - Nonrecurring Fair Value Measurements.

(d) Includes NEER's tax benefits related to PTCs and in 2013 also includes after-tax charges of $342 million associated with the impairment of the Spain solar projects.  See Note 3 - Nonrecurring Fair Value Measurements and Note 4.

(e) See Note 5.

33

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

	March 31, 2014								December 31, 2013
	FPL		NEER		Corporate and Other		NEE Consoli- dated		FPL		NEER		Corporate and Other		NEE Consoli- dated
							(millions)
Total assets	$	37,189	$	30,335	$	2,807	$	70,331	$	36,488	$	30,154	$	2,664	$	69,306

11.  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.  Most of NEECH's debt, including its debentures, and payment guarantees are fully and unconditionally guaranteed by NEE.  Condensed consolidating financial information is as follows:

Condensed Consolidating Statements of Income

	Three Months Ended March 31,
	2014												2013(a)
	NEE (Guarantor)			NEECH			Other(b)			NEE Consoli- dated			NEE (Guarantor)			NEECH			Other(b)			NEE Consoli- dated
										(millions)
Operating revenues	$	—		$	1,142		$	2,532		$	3,674		$	—		$	1,094		$	2,185		$	3,279
Operating expenses	(4		)	(1,032		)	(1,900		)	(2,936		)	(3		)	(1,200		)	(1,642		)	(2,845		)
Interest expense	(2		)	(216		)	(101		)	(319		)	(2		)	(170		)	(100		)	(272		)
Equity in earnings of subsidiaries	435			—			(435		)	—			249			—			(249		)	—
Other income (deductions) - net	1			148			15			164			(2		)	5			20			23
Income (loss) from continuing operations before income taxes	430			42			111			583			242			(271		)	214			185
Income tax expense (benefit)	—			(46		)	199			153			(15		)	(16		)	175			144
Income (loss) from continuing operations	430			88			(88		)	430			257			(255		)	39			41
Gain from discontinued operations, net of income taxes	—			—			—			—			15			216			—			231
Net income (loss)	$	430		$	88		$	(88	)	$	430		$	272		$	(39	)	$	39		$	272

————————————

(a)  Certain amounts were restated to conform to current year's presentation.  See Note 3 - Nonrecurring Fair Value Measurements.

(b)  Represents FPL and consolidating adjustments.

Condensed Consolidating Statements of Comprehensive Income

	Three Months Ended March 31,
	2014									2013
	NEE (Guarantor)		NEECH		Other(a)			NEE Consoli- dated		NEE (Guarantor)		NEECH		Other(a)			NEE Consoli- dated
								(millions)
Comprehensive income (loss)	$	395	$	48	$	(48	)	$	395	$	391	$	73	$	(73	)	$	391

————————————

(a) Represents FPL and consolidating adjustments.

34

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

Condensed Consolidating Balance Sheets

	March 31, 2014												December 31, 2013
	NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated			NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	$	31		$	29,634		$	40,702		$	70,367		$	31		$	29,511		$	39,906		$	69,448
Less accumulated depreciation and amortization	(11		)	(5,965		)	(11,085		)	(17,061		)	(10		)	(5,774		)	(10,944		)	(16,728		)
Total property, plant and equipment - net	20			23,669			29,617			53,306			21			23,737			28,962			52,720
CURRENT ASSETS
Cash and cash equivalents	5			445			38			488			—			418			20			438
Receivables	121			2,107			323			2,551			78			1,542			669			2,289
Other	210			1,623			1,269			3,102			6			1,814			1,295			3,115
Total current assets	336			4,175			1,630			6,141			84			3,774			1,984			5,842
OTHER ASSETS
Investment in subsidiaries	17,962			—			(17,962		)	—			17,910			—			(17,910		)	—
Other	764			5,129			4,991			10,884			694			5,129			4,921			10,744
Total other assets	18,726			5,129			(12,971		)	10,884			18,604			5,129			(12,989		)	10,744
TOTAL ASSETS	$	19,082		$	32,973		$	18,276		$	70,331		$	18,709		$	32,640		$	17,957		$	69,306
CAPITALIZATION
Common shareholders' equity	$	18,160		$	4,432		$	(4,432	)	$	18,160		$	18,040		$	4,816		$	(4,816	)	$	18,040
Long-term debt	—			15,381			8,443			23,824			—			15,496			8,473			23,969
Total capitalization	18,160			19,813			4,011			41,984			18,040			20,312			3,657			42,009
CURRENT LIABILITIES
Debt due within one year	—			5,009			682			5,691			—			3,896			561			4,457
Accounts payable	—			758			692			1,450			—			589			611			1,200
Other	390			1,864			897			3,151			199			2,203			1,130			3,532
Total current liabilities	390			7,631			2,271			10,292			199			6,688			2,302			9,189
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	—			575			1,302			1,877			—			565			1,285			1,850
Deferred income taxes	251			1,982			6,073			8,306			166			1,963			6,015			8,144
Other	281			2,972			4,619			7,872			304			3,112			4,698			8,114
Total other liabilities and deferred credits	532			5,529			11,994			18,055			470			5,640			11,998			18,108
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	19,082		$	32,973		$	18,276		$	70,331		$	18,709		$	32,640		$	17,957		$	69,306

————————————

(a) Represents FPL and consolidating adjustments.

35

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Concluded)

(unaudited)

Condensed Consolidating Statements of Cash Flows

	Three Months Ended March 31,
	2014												2013
	NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated			NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
NET CASH PROVIDED BY OPERATING ACTIVITIES	$	428		$	147		$	442		$	1,017		$	350		$	295		$	437		$	1,082
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	—			(798		)	(1,068		)	(1,866		)	—			(1,046		)	(821		)	(1,867		)
Capital contribution to FPL	(100		)	—			100			—			—			—			—			—
Cash grants under the Recovery Act	—			—			—			—			—			170			—			170
Change in loan proceeds restricted for construction	—			(28		)	—			(28		)	—			112			—			112
Other - net	—			58			(6		)	52			(52		)	29			30			7
Net cash used in investing activities	(100		)	(768		)	(974		)	(1,842		)	(52		)	(735		)	(791		)	(1,578		)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	—			655			—			655			—			623			—			623
Retirements of long-term debt	—			(688		)	(29		)	(717		)	—			(496		)	(427		)	(923		)
Net change in short-term debt	—			1,059			120			1,179			—			166			800			966
Dividends on common stock	(315		)	—			—			(315		)	(279		)	—			—			(279		)
Other - net	(8		)	(378		)	459			73			(21		)	39			(23		)	(5		)
Net cash provided by (used in) financing activities	(323		)	648			550			875			(300		)	332			350			382
Net increase (decrease) in cash and cash equivalents	5			27			18			50			(2		)	(108		)	(4		)	(114		)
Cash and cash equivalents at beginning of period	—			418			20			438			2			287			40			329
Cash and cash equivalents at end of period	$	5		$	445		$	38		$	488		$	—		$	179		$	36		$	215

————————————

(a) Represents FPL and consolidating adjustments.

36

Item 2.  Management's Discussion and Analysis of Financial Condition and Results of Operations

OVERVIEW

NEE’s operating performance is driven primarily by the operations of its two principal subsidiaries, FPL, which serves approximately 4.7 million customer accounts in Florida and is one of the largest rate-regulated electric utilities in the U.S., and NEER, which together with affiliated entities is the largest generator in North Americaof renewable energy from the wind and sun.  The table below presents NEE’s net income (loss)and earnings (loss) per share by reportable segment - FPL, NEER andCorporate and Other, which is primarily comprised of the operating results of NEET, FPL FiberNet and other business activities, as well as other income and expense items, including interest expense, income taxes and eliminating entries (see Note 10for additional segment information, including reported results from continuing operations).The following discussions should be read in conjunction with the Notes contained hereinand Management's Discussion and Analysis of Financial Condition and Results of Operations (Management's Discussion) appearing in the 2013 Form 10-K.The results of operations for an interim period generally will not give a true indication of results for the year.In the following discussions, all comparisons are with the corresponding items in the prior year period.

	Net Income (Loss)						Earnings (Loss) Per Share, assuming dilution
	Three Months Ended   March 31,						Three Months Ended   March 31,
	2014			2013			2014			2013
	(millions)
FPL	$	347		$	288		$	0.79		$	0.68
NEER(a)	86			(40		)	0.20			(0.09		)
Corporate and Other	(3		)	24			(0.01		)	0.05
NEE	$	430		$	272		$	0.98		$	0.64

______________________

(a) NEER’s results reflect an allocation of interest expense from NEECH based on a deemed capital structure of 70% debt and allocated shared service costs.

Adjusted Earnings

NEE prepares its financial statements under generally accepted accounting principles in the U.S. (GAAP).  However, management uses earnings excluding certain items (adjusted earnings), a non-GAAP financial measure, internally for financial planning, for analysis of performance, for reporting of results to the Board of Directors and as an input in determining performance-based compensation under NEE’s employee incentive compensation plans.  NEE also uses adjusted earnings when communicating its financial results and earnings outlook to investors.  NEE’s management believes adjusted earnings provides a more meaningful representation of the company’s fundamental earnings power.  Although the excluded amounts are properly included in the determination of net income under GAAP, management believes that the amount and/or nature of such items make period to period comparisons of operations difficult and potentially confusing.  Adjusted earnings do not represent a substitute for net income, as prepared under GAAP.

Adjusted earnings exclude the unrealized mark-to-market effect of non-qualifying hedges (as described below) and other than temporary impairment (OTTI) losses on securities held in NEER’s nuclear decommissioning funds, net of the reversal of previously recognized OTTI losses on securities sold and losses on securities where price recovery was deemed unlikely (collectively, OTTI reversals).  However, other adjustments may be made from time to time with the intent to provide more meaningful and comparable results of ongoing operations.

NEE and NEER segregate into two categories unrealized mark-to-market gains and losses on derivative transactions.The first category, referred to as non-qualifying hedges, represents certain energy derivative transactions, and, beginning in the second quarter of 2013 certain interest rate derivative transactions, entered into as economic hedges, which do not meet the requirements for hedge accounting, or for which hedge accounting treatment is not elected or has been discontinued.  Changes in the fair value of those transactions are marked to market and reported in the consolidated statements of income, resulting in earnings volatility because the economic offset to the positions are not marked to market.As a consequence, NEE's net income reflects only the movement in one part of economically-linked transactions.  For example, a gain (loss) in the non-qualifying hedge category for certain energy derivatives is offset by decreases (increases) in the fair value of related physical asset positions in the portfolio or contracts, which are not marked to market under GAAP. For this reason, NEE's management views results expressed excluding the unrealized mark-to-market impact of the non-qualifying hedges as a meaningful measure of current period performance.  The second category, referred to as trading activities, which is included in adjusted earnings, represents the net unrealized effect of actively traded positions entered into to take advantage of expected market price movements and all other commodity hedging activities.  At FPL, substantially all changes in the fair value of energy derivative transactions are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the fuel clause.See Note2.

37

During the three months ended March 31, 2013, an after-tax gain from discontinued operations of $231 million was recorded in NEE's condensed consolidated statements of income related to the March 2013 hydro sale.  In addition, during the three months ended March 31, 2013, NEER recorded an after-tax loss of $43 million associated with the decision to pursue the sale of Maine fossil.  During the three months ended March 31, 2014, NEER decided not to pursue the sale of Maine fossil and recorded an after-tax gain of $12 million to increase Maine fossil's carrying value to its estimated fair value.  See Note 3 - Nonrecurring Fair Value Measurements.  During the three months ended March 31, 2013, NEER recorded an impairment of $300 million and other related charges ($342 million after-tax) related to the Spain solar projects in NEE's condensed consolidated statements of income.  See Note 3 - Nonrecurring Fair Value Measurements and Note 9 - Spain Solar Projects. In order to make period to period comparisons more meaningful, adjusted earnings also exclude the after-tax gain from discontinued operations, the after-tax gain (loss) associated with Maine fossil, the after-tax charges associated with the impairment of the Spain solar projects and, in 2014, the after-tax operating results associated with the Spain solar projects.

The following table provides details of the adjustments to net income considered in computing NEE's adjusted earnings discussed above.

	Three Months Ended   March 31,
	2014			2013
	(millions)
Net unrealized mark-to-market after-tax losses from non-qualifying hedge activity(a)	$	(126	)	$	(52	)
Income from OTTI after-tax losses on securities held in NEER's nuclear decommissioning funds, net of OTTI reversals	$	2		$	3
After-tax gain from discontinued operations(b)	$	—		$	231
After-tax gain (loss) associated with Maine fossil(c)	$	12		$	(43	)
After-tax charges recorded by NEER associated with the impairment of the Spain solar projects	$	—		$	(342	)
After-tax operating loss of NEER's Spain solar projects	$	(15	)	$	—

____________________

(a) For the three months ended March 31, 2014 and 2013, approximately $124 million and $53 million of losses, respectively, are included in NEER's net income; the balance is included in Corporate and Other.

(b) For the three months ended March 31, 2013, $216 million of the gain is included in NEER's net income; the balance is included in Corporate and Other.

(c) For the three months ended March 31, 2014, the gain is included in NEER's net income.  For the three months ended March 31, 2013, $41 million of the loss is included in NEER's net income; the balance is included in Corporate and Other.

The change in unrealized mark-to-market activity from non-qualifying hedges is primarily attributable to changes in forward power and natural gas prices and interest rates, as well as the reversal of previously recognized unrealized mark-to-market gains or losses as the underlying transactions were realized.

RESULTS OF OPERATIONS

Summary

NEE's net income for the three months ended March 31, 2014 was higher than the prior period by $158 million, or 34 cents per share, reflecting higher results at NEER and FPL.

FPL's increase in net income for thethree months ended March 31, 2014was primarily driven by continued investments in plant in service while earning an 11.22% return on common equity as determined for regulatory purposes (regulatory ROE) on its retail rate base.

NEER's net income increased for thethree months ended March 31, 2014primarily due to the absence of $342 million of after-tax charges associated with the impairment of the Spain solar projects, partly offset by the absence of the $216 million after-tax gain from discontinued operations, both recorded in 2013.  NEER's results also reflect increased earnings on new investments and existing assets, as well as lower results from the customer supply and proprietary trading businesses and higher net unrealized losses from non-qualifying hedging activity.

Corporate and Other's results decreased for thethree months ended March 31, 2014primarily due to consolidating tax adjustments and higherinvestment losses.

NEE's effective income tax rates for the three months ended March 31, 2014 and 2013 were approximately 26% and 78%, respectively.  The rate for the three months ended March 31, 2013 reflects the establishment of a full valuation allowance during that period on the deferred tax assets associated with the Spain solar projects (see Note 3 - Nonrecurring Fair Value Measurements and Note 4).  The rates for all periods reflect the effect of PTCs for wind projects at NEER and deferred income tax benefits associated with convertible ITCs under the Recovery Act.PTCs and deferred income tax benefits associated with convertible ITCs can significantly affect NEE's effective income tax rate depending on the amount of pretax income.The amount of PTCs recognized

38

can be significantly affected by wind generation and by PTC roll off.PTCs for the three months ended March 31, 2014 and 2013 were approximately $49 million and $59 million, respectively.  Deferred income tax benefits associated with convertible ITCs for the three months ended March 31, 2014 and 2013 were approximately $12 million and $13 million, respectively.  See Note 4.

FPL:  Results of Operations

FPL’s net income for the three months ended March 31, 2014 and 2013 was $347 million and $288 million, respectively, representing an increase of $59 million.

The use of reserve amortization is permitted by a January 2013 FPSC final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2012 rate agreement). In order to earn a targeted regulatory ROE, subject to limitations provided in the 2012 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 other operations and maintenance (O&M) expenses, depreciation and amortization, interest and tax expenses.  The drivers of FPL's net income not reflected in the reserve amortization calculation include wholesale and transmission service revenues and expenses, cost recovery clause revenues and expenses, theequity component of AFUDC (AFUDC - equity) and costs not allowed to be recovered by the FPSC.  During the three months ended March 31, 2014 and 2013, FPL recorded reserve amortization of $125 million and $137 million, respectively.

FPL's regulatory ROE for the twelve months ended March 31, 2014 was 11.22% compared to 11.0% in the prior year period.  The 2014 regulatory ROE of 11.22% reflects approximately $32 million of after-tax charges recorded in 2013 associated with an initiative focused mainly on improving productivity and reducing O&M expenses (cost savings initiative).  These charges were not offset by additional reserve amortization.Excluding the impact of these charges, FPL's regulatory ROE would have been approximately 11.50%, which is FPL's targeted regulatory ROE for 2014.  The $59 million increase in FPL's net income for the three months ended March 31, 2014 was primarily driven by:

• higher earnings of approximately $29 million related to the increase in the regulatory ROE from 11.0% to 11.22%, and

• higher earnings on investment in plant in service of $28 million.  Investment in plant in service grew FPL's average retail rate base for the quarter ended March 31, 2014 by approximately $2.6 billion when compared to the same period last year, reflecting, among other things, the generation power uprates at FPL's nuclear units, themodernized Cape Canaveral facility (Cape Canaveral power plant) and ongoing transmission and distribution additions.

FPL's operating revenues consisted of the following:

	Three Months Ended   March 31,
	2014		2013
	(millions)
Retail base	$	1,136	$	1,030
Fuel cost recovery	914		719
Net deferral of retail fuel revenues	—		(10		)
Other cost recovery clauses and pass-through costs, net of any deferrals	395		388
Other, primarily wholesale and transmission sales, customer-related fees and pole attachment rentals	90		61
Total	$	2,535	$	2,188

Retail Base

Retail base revenues of approximately $25 million were recorded during thethree months ended March 31, 2014, related to new nuclear capacity of approximately 125 MW, which was placed in service in 2013, as permitted by the FPSC's nuclear cost recovery rule.  In addition, retail base revenues related to the Cape Canaveral power plant, which was placed in service in April 2013, amounted to approximately $38 million for the three months ended March 31, 2014.  Approximately $8 million of additional unbilled retail base revenues recorded during the three months ended March 31, 2014 related to the retail base rate increase associated with the modernization of the Riviera Beach power plant that was placed in service on April 1, 2014; the annualized effect of such retail base rate increase is approximately $234 million.

Retail Customer Usage and Growth

For the three months ended March 31, 2014, FPL experienced a 2.4% increase in average usage per retail customer, primarily due to weather conditions and a slight improvement in the Florida economy, which collectively increased revenues by approximately $24 million.  For the three months ended March 31, 2014, FPL experienced a 1.9% increase in the average number of customer accounts, increasing retail base revenues by approximately $11 million.

39

Cost Recovery Clauses

Revenues from fuel and other cost recovery clauses and pass-through costs, such as franchise fees, revenue taxes and storm-related surcharges, are largely a pass-through of costs.  Such revenues also include a return on investment allowed to be recovered through the cost recovery clauses on certain assets, primarily related to nuclear capacity, solar and environmental projects.  For the three months ended March 31, 2014 and 2013, cost recovery clauses contributed approximately $20 million and $27 million, respectively, to FPL’s net income.  The decrease is primarily as a result of the collection in 2014 of retail base revenues related to new nuclear capacity which was placed in service in 2013 (see Retail Base above).  Fluctuations in fuel cost recovery revenues are primarily driven by changes in fuel and energy charges which are included in fuel, purchased power and interchange expense in the condensed consolidated statements of income, as well as by changes in energy sales.  Fluctuations in revenues from other cost recovery clauses and pass-through costs are primarily driven by changes in storm-related surcharges, capacity charges, franchise fee costs, the impact of changes in O&M and depreciation expenses on the underlying cost recovery clause, investment in solar and environmental projects, investment in nuclear capacity until such capacity goes into service and is recovered in base rates, pre-construction costs associated with the development of two additional nuclear units at the Turkey Point site and changes in energy sales.  Capacity charges are included in fuel, purchased power and interchange expense and franchise fee costs are included in taxes other than income taxes and other in the condensed consolidated statements of income.  The increase in fuel cost recovery revenues for the three months ended March 31, 2014is primarily due to a higher average fuel factor of approximately $57 million and higher energy sales of $52 million.  In addition, gas sales associated with an incentive mechanism allowed under the 2012 rate agreement (incentive gas sales) and higher interchange power sales increased fuel cost recovery revenues by approximately $86 million.

Other

The increase in other revenues reflects higher wholesale revenues of approximately $24 million associated with an increase in contracted load served under existing contracts.

Other Items Impacting FPL's Condensed Consolidated Statements of Income

Fuel, Purchased Power and Interchange Expense

The major components of FPL's fuel, purchased power and interchange expense are as follows:

	Three Months Ended   March 31,
	2014		2013
	(millions)
Fuel and energy charges during the period	$	904	$	709
Net deferral of retail fuel costs	8		—
Other, primarily capacity charges, net of any capacity deferral	124		111
Total	$	1,036	$	820

The increase in fuel and energy charges for the three months ended March 31, 2014 reflects approximately $92 million of higher fuel and energy prices, $69 million related to higher energy sales and $34 million of gas purchased for incentive gas sales.

O&M Expenses

FPL's O&M expenses decreased$1 million for the three months ended March 31, 2014 reflecting savings from the cost savings initiative offset by higher costs recoverable through cost recovery clauses, which are essentially pass-through costs, and higher plant overhaul costs.

Depreciation and Amortization Expense

The major components of FPL’s depreciation and amortization expense are as follows:

	Three Months Ended   March 31,
	2014			2013
	(millions)
Reserve amortization recorded under the 2012 rate agreement	$	(125	)	$	(137	)
Other depreciation and amortization recovered under base rates	295			270
Depreciation and amortization recovered under cost recovery clauses and securitized storm-recovery cost amortization	39			48
Total	$	209		$	181

40

The reserve amortization recorded in the current period was lower than amortization recorded in the prior year period primarily due to additional base revenues collected in 2014.The reserve amortization recorded for the three months ended March 31, 2014 and 2013 reflects the amortization of a depreciation and fossil dismantlement reserve provided under the 2012 rate agreement; at March 31, 2014, approximately $120 million of this reserve remains available for future amortization.  Reserve amortization is recorded as a reduction of regulatory liabilities - accrued asset removal costs on the condensed consolidated balance sheets.  The increase in other depreciation and amortization expense recovered under base rates for the three months ended March 31, 2014 is primarily due to higher plant in service balances.The decrease in depreciation and amortization recovered under cost recovery clauses and securitized storm-recovery cost amortization for the three months ended March 31, 2014 is primarily due to recoveries of prior year investment under the FPSC's nuclear cost recovery rule.

Taxes Other Than Income Taxes and Other

Taxes other than income taxes and other increased $15 million for the three months ended March 31, 2014, primarily due to higher property taxes reflecting growth in plant in service balances, as well as higher franchise and revenue taxes, both of which are pass-through costs, partly offset by lower payroll taxes.

AFUDC - Equity

The decrease inAFUDC - equityfor the three months ended March 31, 2014is primarily due to lower AFUDC - equity associated with the Cape Canaveral power plant which was placed in service in April 2013, partly offset by additional AFUDC - equity recorded on construction expenditures associated with the Riviera Beach and Port Everglades modernization projects.

Major Capital Projects

During the three months ended March 31, 2014, FPL began construction on the modernization of its Port Everglades power plant.  In April 2014, FPL placed in service an approximately 1,200 MW natural gas-fired combined-cycle modernized unit at its Riviera Beach power plant.

NEER: Results of Operations

NEER’s net income (loss) forthe three months ended March 31, 2014 and 2013was$86 millionand$(40) million, respectively, representing an increase of$126 million.  The primary drivers, on an after-tax basis, of the change are in the following table.  The 99.8 MW associated with theSpain solar projectsand the related operating results are not included in new investments data below.

	Increase (Decrease) From Prior Period
	Three Months Ended   March 31, 2014
	(millions)
New investments(a)	$	25
Existing assets(a)	61
Gas infrastructure(b)	2
Customer supply and proprietary power and gas trading(b)	(50		)
Interest expense, differential membership costs and other	(4		)
Change in unrealized mark-to-market non-qualifying hedge activity(c)(d)	(71		)
Change in OTTI losses on securities held in nuclear decommissioning funds, net of OTTI reversals(d)	(1		)
Gain on 2013 discontinued operations(e)	(216		)
Change in Maine fossil gain/loss(f)	53
Charges associated with the 2013 impairment of the Spain solar projects(f)	342
Operating loss of the Spain solar projects(f)	(15		)
Net income increase	$	126

______________________

(a) Includes PTCs and state ITCs on wind projects and, for new investments, deferred income tax and other benefits associated with convertible ITCs but excludes allocation of interest expense or corporate general and administrative expenses.  Results from new projects are included in new investments during the first twelve months of operation.  A project's results are included in existing assets beginning with the thirteenth month of operation.

(b) Excludes allocation of interest expense or corporate general and administrative expenses.

(c) See Note 2 and Overview - Adjusted Earnings related to derivative instruments.

(d) See table in Overview - Adjusted Earnings for additional detail.

(e) See Note 5 and Overview - Adjusted Earnings for additional information.

(f) See Note 3 - Nonrecurring Fair Value Measurements and Overview - Adjusted Earnings for additional information.

New Investments

Results from new investmentsfor the three months ended March 31, 2014increased primarily due to:

• the addition of approximately 449 MW of wind generation during or after the three months ended March 31, 2013, and

• higher deferred income tax and other benefits associated with convertible ITCs of $5 million.

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Existing Assets

Results from NEER's existing asset portfolio for the three months ended March 31, 2014 increased primarily due to:

• higher wind generation of approximately $33 million reflecting stronger wind resource,

• higher results at Seabrook and Point Beach Nuclear Power Plant of approximately $25 million, primarily due to gains on sales of securities held in NEER's nuclear decommissioning funds,

• increased results of $13 million at Maine fossil due to additional generation and favorable pricing related to extreme winter weather, and

• increased results of $9 million from merchant assets in the Electric Reliability Council of Texas (ERCOT) region due to favorable market conditions and lower operating costs,

partly offset by,

• PTC roll off of $11 million, and

• lower results of $12 million due to the absence of the hydro assets which were sold in the first quarter of 2013.

Customer Supply and Proprietary Power and Gas Trading

Results from customer supply and proprietary power and gas trading decreasedfor the three months ended March 31, 2014 primarily due to lower results in the customer supply business reflecting the impact of extreme winter weather and market conditions in the Northeast on the full requirements business, partly offset by higher power and gas trading results.

Interest Expense, Differential Membership Costs and Other

For the three months ended March 31, 2014, interest expense, differential membership costs and other reflects higher borrowing and other costs to support the growth of the business, partly offset by the absence of certain unfavorable income tax adjustments recorded in 2013.

Other Factors

Supplemental to the primary drivers of the changes in net income discussed above, the discussion below describes changes in certain line items set forth in NEE's condensed consolidated statements of income as they relate to NEER.

Operating Revenues

Operating revenues for the three months ended March 31, 2014 increased$18 million primarily due to:

• higher revenues from new investments of approximately $54 million, including $15 million associated with the Spain solar projects, and

• higher revenues from existing assets primarily due to higher wind generation due to favorable wind resource and higher revenues in the New England Power Pool (NEPOOL) and ERCOT regions primarily due to favorable market conditions, partly offset by lower customer supply and proprietary power and gas trading revenues primarily due to extreme winter weather (collectively, $33 million),

partly offset by,

• higher unrealized mark-to-market losses from non-qualifying hedges ($149 million for the three months ended March 31, 2014 compared to $100 million of losses on such hedges for the comparable period in 2013).

Operating Expenses

Operating expenses for the three months ended March 31, 2014 decreased $197 million primarily due to:

• the absence of a $300 million impairment charge in 2013 related to the Spain solar projects,

partly offset by,

• higher fuel expense primarily in the NEPOOL and ERCOT regions (collectively, $93 million), and

• higher operating expenses associated with new investments of approximately $32 million, including $11 million associated with the Spain solar projects.

Interest Expense

NEER’s interest expense forthe three months ended March 31, 2014increased$52million primarily due tohigher average debt balances.  In addition, NEER’s interest expense forthe three months ended March 31, 2014reflects a $27 million unfavorable change in the fair value of cash flow hedges related to interest rate swaps for which hedge accounting was discontinued in the second quarter of 2013 (see Note 2 and Overview - Adjusted Earnings).  NEER’s interest expense forthe three months ended March 31, 2014also includes approximately $16 million of additional interest expense associated with the Spain solar projects, primarily due to the absence of capitalized interest in the current period as the project was placed in service in June 2013.

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Benefits Associated with Differential Membership Interests - Net

Benefits associated with differential membership interests - net in NEE's condensed consolidated statements of income forall periods presentedreflect benefits recognized by NEER as third-party investors received their portion of the economic attributes, including income tax attributes, of the underlying wind project, net of associated costs.

Gains on Disposal of Assets - Net

Gains on disposal of assets - net in NEE's condensed consolidated statements of income for the three months ended March 31, 2014 and 2013 primarily reflect gains on sales of securities held in NEER's nuclear decommissioning funds and, for these respective periods, include approximately $5 million and $8 million of OTTI reversals.

Tax Credits and Benefits

PTCs from NEER’s wind projects are reflected in NEER’s earnings.  PTCs are recognized as wind energy is generated and sold based on a per kWh rate prescribed in applicable federal and state statutes.  A portion of the PTCs have been allocated to investors in connection with the sales of differential membership interests.  Also see Summary above andNote 4 for a discussion of PTCs and deferred income tax benefits associated with convertible ITCs and benefits associated with differential membership interests - net above.

Major Capital Projects

During the three months ended March 31, 2014, NEER added approximately 75 MW of new U.S. wind generation and 165 MW of new U.S. solar generation. In addition to the existing plans to add approximately 805 MW of new contracted solar generation during 2014 through 2016, NEER continues to pursue additional solar opportunities including possibly one large 200 MW to 250 MW project and a development pipeline of smaller 10 MW to 40 MW projects.

Corporate and Other: Results of Operations

Corporate and Other is primarily comprised of the operating results of NEET, FPL FiberNet and other business activities, as well as corporate interest income and expenses.  Corporate and Other allocates non-utility interest expense and shared service costs to NEER.  Interest expense is allocated based on a deemed capital structure of 70% debt and, for purposes of allocating non-utility interest expense, the liability associated with differential membership interests sold by NEER’s subsidiaries is included with debt.  Each subsidiary’s income taxes are calculated based on 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 Corporate and Other.  The major components of Corporate and Other’s results, on an after-tax basis, are as follows:

	Three Months Ended   March 31,
	2014			2013
	(millions)
Interest expense, net of allocations to NEER	$	(25	)	$	(28	)
Interest income	8			8
Federal and state income tax benefits	8			26
Other	6			18
Net income (loss)	$	(3	)	$	24

The decrease in interest expense, net of allocations to NEER, for the three months ended March 31, 2014 primarily relates to a higher allocation of interest costs to NEER reflecting a need for additional capital at NEER.  The federal and state income tax benefits for both periods reflect consolidating income tax adjustments and, for the three months ended March 31, 2013, also include a $15 millionincome tax benefit recorded as a gain from discontinued operations, net of federal income taxes (see Overview - Adjusted Earnings and Note 5).  Other includes all other corporate income and expenses, as well as other business activities.  The decrease for the three months ended March 31, 2014 reflects higher investment losses recorded in 2014 and lower results from NEET.

LIQUIDITY AND CAPITAL RESOURCES

NEE and its subsidiaries, including FPL, require funds to support and grow their businesses.  These funds are used for, among other things, working capital, capital expenditures, investments in or acquisitions of assets and businesses, payment of maturing debt obligations and, from time to time, redemption or repurchase of outstanding debt or equity securities.  It is anticipated that these requirements will be satisfied through a combination of cash flows from operations, short- and long-term borrowings, the issuance, from time to time, of short- and long-term debt and equity securities and proceeds from the sale of differential membership interests, consistent with NEE’s and FPL’s objective of maintaining, on a long-term basis, a capital structure that will support a

43

strong investment grade credit rating.  NEE, FPL and NEECH rely on access to credit and capital markets as significant sources of liquidity for capital requirements and other operations that are not satisfied by operating cash flows.  The inability of NEE, FPL and NEECH to maintain their current credit ratings could affect their ability to raise short- and long-term capital, their cost of capital and the execution of their respective financing strategies, and could require the posting of additional collateral under certain agreements.

Cash Flows

Sources and uses of NEE's and FPL's cash for the three months ended March 31, 2014 and 2013 were as follows:

	NEE						FPL
	Three Months Ended   March 31,						Three Months Ended   March 31,
	2014			2013			2014			2013
	(millions)
Sources of cash:
Cash flows from operating activities	$	1,017		$	1,082		$	875		$	776
Long-term borrowings and change in loan proceeds restricted for construction	627			735			—			—
Capital contribution from NEE	—			—			100			—
Cash grants under the Recovery Act	—			170			—			—
Issuances of common stock - net	25			8			—			—
Net increase in short-term debt	1,179			966			120			800
Other sources - net	152			23			42			24
Total sources of cash	3,000			2,984			1,137			1,600
Uses of cash:
Capital expenditures, independent power and other investments and nuclear fuel purchases	(1,866		)	(1,867		)	(1,067		)	(821		)
Retirements of long-term debt	(717		)	(923		)	(29		)	(427		)
Dividends	(315		)	(279		)	—			(340		)
Payments to differential membership investors	(22		)	(20		)	—			—
Other uses - net	(30		)	(9		)	(22		)	(17		)
Total uses of cash	(2,950		)	(3,098		)	(1,118		)	(1,605		)
Net increase (decrease) in cash and cash equivalents	$	50		$	(114	)	$	19		$	(5	)

NEE's primary capital requirements are for expanding and enhancing FPL's electric system and generating facilities to continue to provide reliable service to meet customer electricity demands and for funding NEER's investments in independent power and other projects.  The following table provides a summary of the major capital investments for the three months ended March 31, 2014 and 2013.

	Three Months Ended   March 31,
	2014		2013
	(millions)
FPL:
Generation:
New	$	290	$	335
Existing	307		117
Transmission and distribution	288		217
Nuclear fuel	68		11
General and other	30		20
Other, primarily change in accrued property additions and the exclusion of AFUDC - equity	84		121
Total	1,067		821
NEER:
Wind	505		521
Solar	81		237
Nuclear, including nuclear fuel	51		47
Other	138		180
Total	775		985
Corporate and Other	24		61
Total capital expenditures and independent power and other investments and nuclear fuel purchases	$	1,866	$	1,867

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Liquidity

AtMarch 31, 2014, NEE's total net available liquidity was approximately $5.5 billion, of which FPL's portion was approximately $2.9 billion.  The table below provides the components of FPL's and NEECH's net available liquidity atMarch 31, 2014:

										Maturity Date
	FPL			NEECH			Total			FPL	NEECH
				(millions)
Bank revolving line of credit facilities(a)	$	3,000		$	4,850		$	7,850		(b)	(b)
Less letters of credit	(7		)	(1,202		)	(1,209		)
	2,993			3,648			6,641
Revolving credit facility	235			—			235			May 2014
Less borrowings	—			—			—
	235			—			235
Letter of credit facilities(c)	—			250			250				2015
Less letters of credit	—			(241		)	(241		)
	—			9			9
Subtotal	3,228			3,657			6,885
Cash and cash equivalents	38			445			483
Less commercial paper	(324		)	(1,545		)	(1,869		)
Net available liquidity	$	2,942		$	2,557		$	5,499

_______________________

(a) Provide for the funding of loans up to $7,850 million ($3,000 million for FPL) and the issuance of letters of credit up to $6,600 million ($2,500 million for FPL).  The entire amount of the credit facilities is available for general corporate purposes and to provide additional liquidity in the event of a loss to the companies’ or their subsidiaries’ operating facilities (including, in the case of FPL, a transmission and distribution property loss).  FPL’s bank revolving line of credit facilities are also available to support the purchase of $633 million of pollution control, solid waste disposal and industrial development revenue bonds (tax exempt bonds) in the event they are tendered by individual bond holders and not remarketed prior to maturity.

(b) $500 million of FPL's and $750 million of NEECH's bank revolving line of credit facilities expire in 2016, essentially all of the remaining facilities at each of FPL and NEECH expire in 2019.

(c) Only available for the issuance of letters of credit.

Additionally, a NEER subsidiary has five variable rate Canadian revolving credit agreements with original capacity totaling C$1,150 million and expiration dates ranging from October 2014 to 2016.  These facilities are available for general corporate purposes; however, the current intent is to use these facilities for the purchase, development, construction and/or operation of Canadian renewable generating assets.  In order to borrow or issue letters of credit under the terms of these agreements, among other things, NEE is required to maintain a ratio of funded debt to total capitalization that does not exceed a stated ratio.  These agreements also contain certain covenants and default and related acceleration provisions relating to, among other things, failure of NEE to maintain a ratio of funded debt to total capitalization at or below the specified ratio.  The payment obligations under these agreements are ultimately guaranteed by NEE.  As of March 31, 2014, approximately $457 million of capacity remained available.

Capital Support

Letters of Credit, Surety Bonds and Guarantees

Certain subsidiaries of NEE, including FPL, obtain letters of credit and surety bonds and issue guarantees to facilitate commercial transactions with third parties and financings.  Letters of credit, surety bonds and guarantees support, among other things, the buying and selling of wholesale energy commodities, debt and related reserves, capital expenditures for NEER's wind and solar development, nuclear activities and other contractual agreements.  Substantially all of NEE's and FPL's guarantee arrangements are on behalf of their consolidated subsidiaries for their related payment obligations.

In addition, as part of contract negotiations in the normal course of business, NEE and certain of its subsidiaries, including FPL, may agree to make payments to compensate or indemnify other parties for possible future unfavorable financial consequences resulting from specified events.  The specified events may include, but are not limited to, an adverse judgment in a lawsuit, the imposition of additional taxes due to a change in tax law or interpretations of the tax law or the non-receipt of renewable tax credits or proceeds from cash grants under the Recovery Act.  NEE and FPL are unable to develop an estimate of the maximum potential amount of future payments under some of these contracts because events that would obligate them have not yet occurred or, if any such event has occurred, they have not been notified of its occurrence.

In addition, NEE has guaranteed certain payment obligations of NEECH, including most of its debt and all of its debentures and commercial paper issuances, as well as most of its payment guarantees and indemnifications, and NEECH has guaranteed certain debt and other obligations of NEER and its subsidiaries.

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At March 31, 2014, NEE had approximately $1.5 billion of standby letters of credit ($7 million for FPL), approximately $141 million of surety bonds ($22 million for FPL) and approximately $11.3 billion notional amount of guarantees and indemnifications ($18 million for FPL), of which approximately $8.0 billion of letters of credit, guarantees and indemnifications ($11 million for FPL) have expiration dates within the next five years.

Each of NEE and FPL believe it is unlikely that it would incur any liabilities associated with these letters of credit, surety bonds, guarantees and indemnifications.  Accordingly, at March 31, 2014, NEE and FPL did not have any liabilities recorded for these letters of credit, surety bonds, guarantees and indemnifications.

Energy Marketing and Trading and Market Risk Sensitivity

NEE and FPL are exposed to risks associated with adverse changes in commodity prices, interest rates and equity prices.  Financial instruments and positions affecting the financial statements of NEE and FPL described below are held primarily for purposes other than trading.  Market risk is measured as the potential loss in fair value resulting from hypothetical reasonably possible changes in commodity prices, interest rates or equity prices over the next year.  Management has established risk management policies to monitor and manage such market risks, as well as credit risks.

Commodity Price Risk

NEE and FPL use derivative instruments (primarily swaps, options, futures and forwards) to manage the commodity price risk inherent in the purchase and sale of fuel and electricity.  In addition, NEE, through NEER, uses derivatives to optimize the value of its power generation and gas infrastructure assets and engages in power and gas marketing and trading activities to take advantage of expected future favorable price movements.  See Note 2.

The changes in the fair value of NEE's consolidated subsidiaries' energy contract derivative instruments for the three months ended March 31, 2014 were as follows:

				Hedges on Owned Assets
	Trading			Non- Qualifying			FPL Cost Recovery Clauses			NEE Total
	(millions)
Fair value of contracts outstanding at December 31, 2013	$	301		$	563		$	46		$	910
Reclassification to realized at settlement of contracts	36			119			(62		)	93
Inception value of new contracts	(21		)	—			—			(21		)
Net option premium purchases (issuances)	4			1			—			5
Changes in fair value excluding reclassification to realized	(3		)	(272		)	136			(139		)
Fair value of contracts outstanding at March 31, 2014	317			411			120			848
Net margin cash collateral paid (received)										(241		)
Total mark-to-market energy contract net assets at March 31, 2014	$	317		$	411		$	120		$	607

NEE's total mark-to-market energy contract net assets (liabilities) at March 31, 2014 shown above are included on the condensed consolidated balance sheets as follows:

	March 31, 2014
	(millions)
Current derivative assets	$	500
Noncurrent derivative assets	941
Current derivative liabilities	(529		)
Noncurrent derivative liabilities	(305		)
NEE's total mark-to-market energy contract net assets	$	607

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The sources of fair value estimates and maturity of energy contract derivative instruments at March 31, 2014 were as follows:

	Maturity
	2014			2015			2016			2017			2018			Thereafter		Total
	(millions)
Trading:
Quoted prices in active markets for identical assets	$	56		$	50		$	(3	)	$	(2	)	$	—		$	—	$	101
Significant other observable inputs	36			21			44			30			2			3		136
Significant unobservable inputs	(34		)	35			21			24			(1		)	35		80
Total	58			106			62			52			1			38		317
Owned Assets - Non-Qualifying:
Quoted prices in active markets for identical assets	(6		)	(1		)	1			—			—			—		(6		)
Significant other observable inputs	(16		)	(70		)	8			8			1			1		(68		)
Significant unobservable inputs	(3		)	34			57			56			61			280		485
Total	(25		)	(37		)	66			64			62			281		411
Owned Assets - FPL Cost Recovery Clauses:
Quoted prices in active markets for identical assets	—			—			—			—			—			—		—
Significant other observable inputs	116			1			—			—			—			—		117
Significant unobservable inputs	2			—			1			—			—			—		3
Total	118			1			1			—			—			—		120
Total sources of fair value	$	151		$	70		$	129		$	116		$	63		$	319	$	848

The changes in the fair value of NEE's consolidated subsidiaries' energy contract derivative instruments for the three months ended March 31, 2013 were as follows:

				Hedges on Owned Assets
	Trading			Non- Qualifying			FPL Cost Recovery Clauses			NEE Total
	(millions)
Fair value of contracts outstanding at December 31, 2012	$	261		$	674		$	(15	)	$	920
Reclassification to realized at settlement of contracts	(3		)	(10		)	15			2
Inception value of new contracts	3			—			—			3
Net option premium purchases (issuances)	(6		)	(12		)	—			(18		)
Changes in fair value excluding reclassification to realized	39			(78		)	144			105
Fair value of contracts outstanding at March 31, 2013	294			574			144			1,012
Net margin cash collateral paid (received)										(120		)
Total mark-to-market energy contract net assets (liabilities) at March 31, 2013	$	294		$	574		$	144		$	892

With respect to commodities,NEE’s EMC, which is comprised of certain members of senior management, and NEE's chief executive officer are responsible for the overall approval of market risk management policies and the delegation of approval and authorization levels.  The EMC and NEE's chief executive officer receive periodic updates on market positions and related exposures, credit exposures and overall risk management activities.

NEE uses a value-at-risk (VaR) model to measure commodity price market risk in its trading and mark-to-market portfolios.  The VaR is the estimated nominal loss of market value based on a one-day holding period at a 95% confidence level using historical simulation methodology.  As of March 31, 2014 and December 31, 2013, the VaR figures are as follows:

	Trading						Non-Qualifying Hedges and Hedges in FPL Cost Recovery Clauses(a)						Total
	FPL		NEER		NEE		FPL		NEER		NEE		FPL		NEER		NEE
									(millions)
December 31, 2013	$	—	$	2	$	2	$	36	$	54	$	43	$	36	$	55	$	42
March 31, 2014	$	—	$	2	$	2	$	53	$	35	$	34	$	53	$	35	$	35
Average for the three months ended March 31, 2014	$	—	$	4	$	4	$	56	$	44	$	39	$	56	$	46	$	37

______________________

(a) Non-qualifying hedges are employed to reduce the market risk exposure to physical assets or contracts which are not marked to market.  The VaR figures for the non-qualifying hedges and hedges in FPL cost recovery clauses category do not represent the economic exposure to commodity price movements.

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Interest Rate Risk

NEE and FPL are exposed to risk resulting from changes in interest rates as a result of their respective issuances of debt, investments in special use funds and other investments.  NEE and FPL manage their respective interest rate exposure by monitoring current interest rates, entering into interest rate contracts and using a combination of fixed rate and variable rate debt.  Interest rate contracts are used to mitigate and adjust interest rate exposure when deemed appropriate based upon market conditions or when required by financing agreements.

The following are estimates of the fair value of NEE's and FPL's financial instruments that are exposed to interest rate risk:

	March 31, 2014							December 31, 2013
	Carrying Amount			Estimated Fair Value				Carrying Amount			Estimated Fair Value
	(millions)
NEE:
Fixed income securities:
Special use funds	$	2,259		$	2,259		(a)	$	2,195		$	2,195		(a)
Other investments:
Debt securities	$	120		$	120		(a)	$	113		$	113		(a)
Primarily notes receivable	$	528		$	667		(b)	$	531		$	627		(b)
Long-term debt, including current maturities	$	27,639		$	28,782		(c)	$	27,728		$	28,612		(c)
Interest rate contracts - net unrealized losses	$	(157	)	$	(157	)	(d)	$	(130	)	$	(130	)	(d)
FPL:
Fixed income securities - special use funds	$	1,761		$	1,761		(a)	$	1,735		$	1,735		(a)
Long-term debt, including current maturities	$	8,801		$	9,384		(c)	$	8,829		$	9,451		(c)

————————————

(a) Primarily estimated using quoted market prices for these or similar issues.

(b) Primarily estimated using a discounted cash flow valuation technique based on certain observable yield curves and indices considering the credit profile of the borrower.

(c) Estimated using either quoted market prices for the same or similar issues or discounted cash flow valuation technique, considering the current credit spread of the debtor.

(d) Modeled internally using discounted cash flow valuation technique and applying a credit valuation adjustment.

The special use funds of NEE and FPL consist of restricted funds set aside to cover the cost of storm damage for FPL and for the decommissioning of NEE's and FPL's nuclear power plants.  A portion of these funds is invested in fixed income debt securities primarily carried at estimated fair value.  At FPL, changes in fair value, including any OTTI losses, result in a corresponding adjustment to the related liability accounts based on current regulatory treatment.  The changes in fair value of NEE's non-rate regulated operations result in a corresponding adjustment to OCI, except for impairments deemed to be other than temporary, including any credit losses, which are reported in current period earnings.  Because the funds set aside by FPL for storm damage could be needed at any time, the related investments are generally more liquid and, therefore, are less sensitive to changes in interest rates.  The nuclear decommissioning funds, in contrast, are generally invested in longer-term securities, as decommissioning activities are not scheduled to begin until at least 2030 (2032 at FPL).

As of March 31, 2014, NEE had interest rate contracts with a notional amount of approximately $6.8 billion related to long-term debt issuances, of which $2.2 billion are fair value hedges at NEECH that effectively convert fixed-rate debt to a variable-rate instrument.  The remaining $4.6 billion of notional amount of interest rate contracts relate to cash flow hedges to manage exposure to the variability of cash flows associated with variable-rate debt instruments, all of which relate to NEER debt issuances.  At March 31, 2014, the estimated fair value of NEE's fair value hedges and cash flow hedges was approximately $14 million and $(171) million, respectively.  See Note 2.

Based upon a hypothetical 10% decrease in interest rates, which is a reasonable near-term market change, the net fair value of NEE's net liabilities would increase by approximately $941 million ($486 million for FPL) at March 31, 2014.

Equity Price Risk

NEE and FPL are exposed to risk resulting from changes in prices for equity securities.  For example, NEE’s nuclear decommissioning reserve funds include marketable equity securities primarily carried at their market value of approximately $2,607 million and $2,585 million ($1,566 million and $1,538 million for FPL) atMarch 31, 2014 and December 31, 2013, respectively.  At March 31, 2014, a hypothetical 10% decrease in the prices quoted by stock exchanges, which is a reasonable near-term market change, would result in a $240 million ($141 million for FPL) reduction in fair value.  For FPL, a corresponding adjustment would be made to the related liability accounts based on current regulatory treatment, and for NEE’s non-rate regulated operations, a corresponding adjustment would be made to OCI to the extent the market value of the securities exceeded amortized cost and to OTTI loss to the extent the market value is below amortized cost.

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Credit Risk

NEE and its subsidiaries are also exposed to credit risk through their energy marketing and trading operations.  Credit risk is the risk that a financial loss will be incurred if a counterparty to a transaction does not fulfill its financial obligation.  NEE manages counterparty credit risk for its subsidiaries with energy marketing and trading operations through established policies, including counterparty credit limits, and in some cases credit enhancements, such as cash prepayments, letters of credit, cash and other collateral and guarantees.

Credit risk is also managed through the use of master netting agreements.  NEE’s credit department monitors current and forward credit exposure to counterparties and their affiliates, both on an individual and an aggregate basis.  For all derivative and contractual transactions, NEE’s energy marketing and trading operations, which includes FPL’s energy marketing and trading division, are exposed to losses in the event of nonperformance by counterparties to these transactions.  Some relevant considerations when assessing NEE’s energy marketing and trading operations’ credit risk exposure include the following:

• Operations are primarily concentrated in the energy industry.

• Trade receivables and other financial instruments are predominately with energy, utility and financial services related companies, as well as municipalities, cooperatives and other trading companies in the U.S.

• Overall credit risk is managed through established credit policies and is overseen by the EMC.

• Prospective and existing customers are reviewed for creditworthiness based upon established standards, with customers not meeting minimum standards providing various credit enhancements or secured payment terms, such as letters of credit or the posting of margin cash collateral.

• Master netting agreements are used to offset cash and non-cash gains and losses arising from derivative instruments with the same counterparty.  NEE’s policy is to have master netting agreements in place with significant counterparties.

Based on NEE’s policies and risk exposures related to credit, NEE and FPL do not anticipate a material adverse effect on their financial statements as a result of counterparty nonperformance.  As of March 31, 2014, approximately 95% of NEE’s and 100% of FPL’s energy marketing and trading counterparty credit risk exposure is associated with companies that have investment grade credit ratings.

49

Item 3.Quantitative and Qualitative Disclosures About Market Risk

See Management's Discussion - Energy Marketing and Trading and Market Risk Sensitivity.

Item 4.  Controls and Procedures

(a) Evaluation of Disclosure Controls and Procedures

As of March 31, 2014, each of NEE and FPL had performed an evaluation, under the supervision and with the participation of its management, including NEE's and FPL's chief executive officer and chief financial officer, of the effectiveness of the design and operation of each company's disclosure controls and procedures (as defined in the Securities Exchange Act of 1934 Rules 13a-15(e) and 15d-15(e)).  Based upon that evaluation, the chief executive officer and the chief financial officer of each of NEE and FPL concluded that the company's disclosure controls and procedures were effective as of March 31, 2014.

(b) Changes in Internal Control Over Financial Reporting

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

PART II - OTHER INFORMATION

Item 1.  Legal Proceedings

NEE and FPL are parties to various legal and regulatory proceedings in the ordinary course of their respective businesses.  For information regarding legal proceedings that could have a material effect on NEE or FPL, see Item 3. Legal Proceedings and Note 13 - Legal Proceedings to Consolidated Financial Statements in the 2013 Form 10-K and Note 9 - Legal Proceedings herein.  Such descriptions are incorporated herein by reference.

Item 1A.  Risk Factors

There have been no material changes from the risk factors disclosed in the 2013 Form 10-K.  The factors discussed in Part I, Item 1A. Risk Factors in the 2013 Form 10-K, as well as other information set forth in this report, which could materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects should be carefully considered.  The risks described in the 2013 Form 10-K are not the only risks facing NEE and FPL.  Additional risks and uncertainties not currently known to NEE or FPL, or that are currently deemed to be immaterial, also may materially adversely affect NEE's or FPL's business, financial condition, results of operations and prospects.

Item 2.  Unregistered Sales of Equity Securities and Use of Proceeds

(c) Information regarding purchases made by NEE of its common stock during the three months ended March 31, 2014 is as follows:

Period	Total Number of Shares Purchased(a)	Average Price Paid Per Share		Total Number of Shares Purchased as Part of a Publicly Announced Program	Maximum Number of Shares that May Yet be Purchased Under the Program(b)
1/1/14 - 1/31/14	—	$	—	—	13,274,748
2/1/14 - 2/28/14	90,045	$	93.26	—	13,274,748
3/1/14 - 3/31/14	480	$	94.84	—	13,274,748
Total	90,525	$	93.27	—

————————————

(a) Includes: (1) in February 2014, shares of common stock withheld from employees to pay certain withholding taxes upon the vesting of stock awards granted to such employees under the NextEra Energy, Inc. Amended and Restated 2011 Long-Term Incentive Plan and the NextEra Energy, Inc. Amended and Restated Long-Term Incentive Plan (former LTIP); and (2) in March 2014, shares of common stock purchased as a reinvestment of dividends by the trustee of a grantor trust in connection with NEE's obligation under a February 2006 grant under the former LTIP to an executive officer of deferred retirement share awards.

(b) In February 2005, NEE's Board of Directors authorized common stock repurchases of up to 20 million shares of common stock over an unspecified period, which authorization was most recently reaffirmed and ratified by the Board of Directors in July 2011.

50

Item 5. Other Information

(a) On April 29, 2014, Lone Star, an indirect wholly-owned subsidiary of NEECH, entered into a note purchase agreement providing for the issuance of $360 million in aggregate principal amount of senior secured notes, which notes Lone Star anticipates issuing in July 2014, subject to Lone Star satisfying certain conditions precedent. The maturity dates of the notes will range from 2021 to 2044. The notes will bear interest at rates ranging from 2.45% to 4.42%, payable semi-annually, with principal payable for $275 million of the notes at maturity with the balance of the principal payable in installments.  Proceeds from the sale of the notes will be used to, among other things, pay down Lone Star’s existing indebtednessand for general corporate purposes.  The notes will be secured by liens on the majority of Lone Star’s transmission assets.  The note purchase agreement contains default and related acceleration provisions relating to, among other things, the failure to make required payments or to observe other covenants in the note purchase agreement and related documents, including a covenant that Lone Star’s ratio of indebtedness to total capitalization not exceed a specified ratio, and certain bankruptcy-related events.

(b) None

(c) Other events

(i) Reference is made to Item 1. Business - FPL - FPL Sources of Generation - Nuclear Operations - Spent Nuclear Fuel - Nuclear Waste Policy Act of 1982, as amended (Nuclear Waste Policy Act) and Item 1. Business - NEER - Generation and Other Operations - NEER Fuel/Technology Mix - Nuclear Facilities - Spent Nuclear Fuel in the 2013 Form 10-K.

In March 2014, the U.S. Court of Appeals for the District of Columbia (D.C. Circuit) denied the U.S. Department of Energy’s (DOE) petition for rehearing regarding the nuclear waste fee.  The DOE has until June 2014 to seek review by the U.S. Supreme Court.  NEE subsidiaries that own and operate nuclear facilities, including FPL, will continue to pay fees to the U.S. government's nuclear waste fund pending implementation of a zero-fee proposal.

(ii) Reference is made to Item 1. Business - NEE Environmental Matters - Environmental Regulations - Clean Air Interstate Rule (CAIR)/Cross-State Air Pollution Rule (CSAPR) in the 2013 Form 10-K.

In April 2014, the U.S. Supreme Court reversed the D.C. Circuit's decision to vacate the CSAPR. The EPA will now determine how to implement the CSAPR and is expected to provide guidance before the end of 2014. Complying with the CSAPR is not expected to have a significant impact on the operations and/or financial results of NEE or FPL.

(iii) Reference is made to Item 1. Business - NEE Environmental Matters - Environmental Regulations - Clean Water Act Section 316(b) in the 2013 Form 10-K.

The issuance of a final rule under Section 316(b) of the Clean Water Act has been delayed.

(iv) Reference is made to Item 1. Business - NEE Environmental Matters - Environmental Regulations in the 2013 Form 10-K.

In March 2014, the EPA issued a proposed rule redefining "waters of the U.S." under the Clean Water Act to add previously unregulated waters to the definition, such as intermittent streams, non-navigable tributaries and adjacent waters.  Under the proposed rule, subsidiaries of NEE could incur increased costs for siting and permitting new projects or when making modifications to existing facilities and transmission and distribution lines.  The ultimate economic and operational impact of the provisions of the proposed rule cannot be determined at this time.  A final rule is not expected before the first quarter of 2015.

(v) In March 2014, NEER decided not to pursue the sale of Maine fossil. This decision resulted in the reclassification of a $67 million ($43 million after-tax) loss on Maine fossil assets from discontinued operations to income from continuing operations in NEE's condensed consolidated statements of income.  See Note 3 - Nonrecurring Fair Value Measurements.  The following table presents summarized financial information for the year ended December 31, 2013 restated to conform to the current period's presentation.

51

	Year Ended December 31, 2013 (millions, except per share amounts)
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	$	2,454
INCOME TAXES	777
INCOME FROM CONTINUING OPERATIONS	1,677
GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	231
NET INCOME	$	1,908
Basic earnings per share of common stock:
Continuing operations	$	3.95
Discontinued operations	0.55
Net income	$	4.50
Earnings per share of common stock - assuming dilution:
Continuing operations	$	3.93
Discontinued operations	0.54
Net income	$	4.47

Item 6.  Exhibits

Exhibit Number	Description	NEE	FPL
*4(a)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated March 11, 2014, creating the 2.700% Debentures, Series Due September 15, 2019 (filed as Exhibit 4 to Form 8-K dated March 11, 2014, File No. 1-8841)	x
*10(a)	NextEra Energy, Inc. Non-Employee Director Compensation Summary effective January 1, 2014 (filed as Exhibit 10(oo) to Form 10-K for the year ended December 31, 2013, File No. 1-8841)	x
*10(b)	Executive Retention Employment Agreement between NextEra Energy, Inc. and Miguel Arechabala dated as of January 1, 2014 (filed as Exhibit 10(bbb) to Form 10-K for the year ended December 31, 2013, File No. 1-8841)	x	x
12(a)	Computation of Ratios	x
12(b)	Computation of Ratios		x
31(a)	Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of NextEra Energy, Inc.	x
31(b)	Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer of NextEra Energy, Inc.	x
31(c)	Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of Florida Power & Light Company		x
31(d)	Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer of Florida Power & Light Company		x
32(a)	Section 1350 Certification of NextEra Energy, Inc.	x
32(b)	Section 1350 Certification of Florida Power & Light Company		x
101.INS	XBRL Instance Document	x	x
101.SCH	XBRL Schema Document	x	x
101.PRE	XBRL Presentation Linkbase Document	x	x
101.CAL	XBRL Calculation Linkbase Document	x	x
101.LAB	XBRL Label Linkbase Document	x	x
101.DEF	XBRL Definition Linkbase Document	x	x

_________________________

*Incorporated herein by reference

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

52

		SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.
Date:	May 1, 2014
		NEXTERA ENERGY, INC. (Registrant)
		CHRIS N. FROGGATT
		Chris N. Froggatt Vice President, Controller and Chief Accounting Officer of NextEra Energy, Inc. (Principal Accounting Officer of NextEra Energy, Inc.)
		FLORIDA POWER & LIGHT COMPANY (Registrant)
		KIMBERLY OUSDAHL
		Kimberly Ousdahl Vice President, Controller and Chief Accounting Officer of Florida Power & Light Company (Principal Accounting Officer of Florida Power & Light Company)

53

EX-12.A

Exhibit 12(a)

NEXTERA ENERGY, INC. AND SUBSIDIARIES

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES AND

RATIO OF EARNINGS TO COMBINED FIXED CHARGES AND PREFERRED STOCK DIVIDENDS^(a) 

	Three Months Ended   March 31, 2014		Year Ended December 31, 2013
	(millions of dollars)
Earnings, as defined:
Income from continuing operations	$	430	$	1,677
Income taxes	153		777
Fixed charges included in the determination of income from continuing operations, as below	340		1,195
Amortization of capitalized interest	9		34
Distributed income of equity method investees	—		33
Less:  Equity in earnings of equity method investees	2		25
Total earnings, as defined	$	930	$	3,691
Fixed charges, as defined:
Interest expense	$	319	$	1,121
Rental interest factor	14		47
Allowance for borrowed funds used during construction	7		27
Fixed charges included in the determination of income from continuing operations	340		1,195
Capitalized interest	29		140
Total fixed charges, as defined	$	369	$	1,335
Ratio of earnings to fixed charges and ratio of earnings to combined fixed charges and preferred stock dividends(a)	2.52		2.76

————————————

(a) NextEra Energy, Inc. has no preference equity securities outstanding; therefore, the ratio of earnings to fixed charges is the same as the ratio of earnings to combined fixed charges and preferred stock dividends.

EX-12.B

Exhibit 12(b)

FLORIDA POWER & LIGHT COMPANY AND SUBSIDIARIES

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES AND

RATIO OF EARNINGS TO COMBINED FIXED CHARGES AND PREFERRED STOCK DIVIDENDS^(a) 

	Three Months Ended   March 31, 2014
	(millions of dollars)
Earnings, as defined:
Net income	$	346.5
Income taxes	198.6
Fixed charges included in the determination of net income, as below	112.2
Total earnings, as defined	$	657.3
Fixed charges, as defined:
Interest expense	$	102.4
Rental interest factor	2.9
Allowance for borrowed funds used during construction	6.9
Total fixed charges, as defined	$	112.2
Ratio of earnings to fixed charges and ratio of earnings to combined fixed charges and preferred stock dividends(a)	5.86

————————————

(a) Florida Power & Light Company has no preference equity securities outstanding; therefore, the ratio of earnings to fixed charges is the same as the ratio of earnings to combined fixed charges and preferred stock dividends.

EX-31.A

Exhibit 31(a)

Rule 13a-14(a)/15d-14(a) Certification

I, James L. Robo, certify that:

1. I have reviewed this Form 10-Q for the quarterly period ended March 31, 2014 of NextEra Energy, Inc. (the registrant);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: May 1, 2014

JAMES L. ROBO

James L. Robo

Chairman, President and Chief Executive Officer

of NextEra Energy, Inc.

EX-31.B

Exhibit 31(b)

Rule 13a-14(a)/15d-14(a) Certification

I, Moray P. Dewhurst, certify that:

1. I have reviewed this Form 10-Q for the quarterly period ended March 31, 2014 of NextEra Energy, Inc. (the registrant);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: May 1, 2014

MORAY P. DEWHURST

Moray P. Dewhurst

Vice Chairman and Chief Financial Officer,

and Executive Vice President - Finance

of NextEra Energy, Inc.

EX-31.C

Exhibit 31(c)

Rule 13a-14(a)/15d-14(a) Certification

I, James L. Robo, certify that:

1. I have reviewed this Form 10-Q for the quarterly period ended March 31, 2014 of Florida Power & Light Company (the registrant);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: May 1, 2014

JAMES L. ROBO

James L. Robo

Chairman and Chief Executive Officer

of Florida Power & Light Company

EX-31.D

Exhibit 31(d)

Rule 13a-14(a)/15d-14(a) Certification

I, Moray P. Dewhurst, certify that:

1. I have reviewed this Form 10-Q for the quarterly period ended March 31, 2014 of Florida Power & Light Company (the registrant);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: May 1, 2014

MORAY P. DEWHURST

Moray P. Dewhurst

Executive Vice President, Finance

and Chief Financial Officer

of Florida Power & Light Company

EX-32.A

Exhibit 32(a)

Section 1350 Certification

We, James L. Robo and Moray P. Dewhurst, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Quarterly Report on Form 10-Q of NextEra Energy, Inc. (the registrant) for the quarterly period ended March 31, 2014 (Report) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

Dated: May 1, 2014

JAMES L. ROBO

James L. Robo

Chairman, President and Chief Executive Officer

of NextEra Energy, Inc.

MORAY P. DEWHURST

Moray P. Dewhurst

Vice Chairman and Chief Financial Officer,

and Executive Vice President - Finance

of NextEra Energy, Inc.

A signed original of this written statement required by Section 906 has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

The foregoing certification is being furnished as an exhibit to the Report pursuant to Item 601(b)(32) of Regulation S-K and Section 906 of the Sarbanes-Oxley Act of 2002 and, accordingly, is not being filed with the Securities and Exchange Commission as part of the Report and is not to be incorporated by reference into any filing of the registrant under the Securities Act of 1933 or the Securities Exchange Act of 1934 (whether made before or after the date of the Report, irrespective of any general incorporation language contained in such filing).

EX-32.B

Exhibit 32(b)

Section 1350 Certification

We, James L. Robo and Moray P. Dewhurst, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Quarterly Report on Form 10-Q of Florida Power & Light Company (the registrant) for the quarterly period ended March 31, 2014 (Report) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

Dated: May 1, 2014

JAMES L. ROBO

James L. Robo

Chairman and Chief Executive Officer of

Florida Power & Light Company

MORAY P. DEWHURST

Moray P. Dewhurst

Executive Vice President, Finance and

Chief Financial Officer of

Florida Power & Light Company

A signed original of this written statement required by Section 906 has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

The foregoing certification is being furnished as an exhibit to the Report pursuant to Item 601(b)(32) of Regulation S-K and Section 906 of the Sarbanes-Oxley Act of 2002 and, accordingly, is not being filed with the Securities and Exchange Commission as part of the Report and is not to be incorporated by reference into any filing of the registrant under the Securities Act of 1933 or the Securities Exchange Act of 1934 (whether made before or after the date of the Report, irrespective of any general incorporation language contained in such filing).

XML

Fair Value Measurements (Fair Value of Instruments Recorded at Carrying Amount) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Held To Maturity Notes Receivable Maturity Date High	2029
Special Use Funds Storm Fund Assets	$ 75
Special use funds: nuclear decommissioning fund assets	4,791
Available for sale debt securities amortized cost	1,941		1,954
Available For Sale Securities Equity Securities Amortized Cost	1,420		1,384
Special Use Funds Nuclear Decommissioning Funds Weighted Average Maturity	6 years
Special Use Funds Storm Fund Weighted Average Maturity	3 years
Carrying Amount [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Recorded at Carrying Amount Fair Value Disclosure	363	[1]	311	[1]
Other Investments Notes Receivable Fair Value Disclosure	528		531
Long Term Debt Including Current Maturities Fair Value Disclosure	27,639		27,728
Estimated Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Recorded at Carrying Amount Fair Value Disclosure	363	[1]	311	[1]
Other Investments Notes Receivable Fair Value Disclosure	667	[2]	627	[2]
Long Term Debt Including Current Maturities Fair Value Disclosure	28,782	[3]	28,612	[3]
Estimated Fair Value [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	18,135		17,921
FPL [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special use funds: nuclear decommissioning fund assets	3,252
Available for sale debt securities amortized cost	1,550		1,595
Available For Sale Securities Equity Securities Amortized Cost	714		694
Special Use Funds Nuclear Decommissioning Funds Weighted Average Maturity	6 years
FPL [Member] | Carrying Amount [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Recorded at Carrying Amount Fair Value Disclosure	251	[1]	200	[1]
Long Term Debt Including Current Maturities Fair Value Disclosure	8,801		8,829
FPL [Member] | Estimated Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Special Use Funds Recorded at Carrying Amount Fair Value Disclosure	251	[1]	200	[1]
Long Term Debt Including Current Maturities Fair Value Disclosure	$ 9,384	[3]	$ 9,451	[3]

[1] Primarily represents investments accounted for under the equity method and loans not measured at fair value on a recurring basis.

[2] Primarily classified as held to maturity. Fair values are primarily estimated using 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. As of March 31, 2014 and December 31, 2013, NEE had no notes receivable reported in non-accrual status.

[3] As of March 31, 2014 and December 31, 2013, for NEE, $18,135 million and $17,921 million, respectively, is estimated using quoted market prices for the same or similar issues (Level 2); the balance is estimated using a discounted cash flow valuation technique, considering the current credit spread of the debtor (Level 3). For FPL, estimated using quoted market prices for the same or similar issues (Level 2).

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Commitments and Contingencies (Long-term Purchase Commitment) (Details) (USD $)			3 Months Ended																3 Months Ended				0 Months Ended
	Mar. 31, 2014 NextEra Energy Resources [Member]	Mar. 31, 2014 NextEra Energy Resources [Member] Contract Group 1 [Member]	Mar. 31, 2014 FPL [Member]	Mar. 31, 2013 FPL [Member]	Mar. 31, 2014 FPL [Member] Jea And Southern Subsidiaries Contract Range 1 [Member] MW	Mar. 31, 2014 FPL [Member] Jea And Southern Subsidiaries Contract Range 2 [Member] MW	Mar. 31, 2014 FPL [Member] Qualifying Facilities Contracts [Member] MW	Mar. 31, 2014 FPL [Member] Natural Gas, Coal, And Oil, Including Transportation And Storage [Member]	Mar. 31, 2014 FPL [Member] Qualifying Facilities Capacity Payments [Member]		Mar. 31, 2014 FPL [Member] Jea And Southern Subsidiaries Capacity Payments [Member]		Mar. 31, 2014 FPL [Member] Natural Gas, Including Transportation And Storage, Contract Minimum Payments [Member]		Mar. 31, 2014 FPL [Member] Coal Contract Minimum Payments [Member]		Mar. 31, 2014 Corporate and Other [Member]		Mar. 31, 2014 Minimum [Member] NextEra Energy Resources [Member] Contract Group 1 [Member]	Mar. 31, 2014 Minimum [Member] NextEra Energy Resources [Member] Contract Group 2 [Member]	Mar. 31, 2014 Maximum [Member] NextEra Energy Resources [Member] Contract Group 1 [Member]	Mar. 31, 2014 Maximum [Member] NextEra Energy Resources [Member] Contract Group 2 [Member]	May 01, 2017 Scenario, Forecast [Member] FPL [Member] Sabal Trail and Florida Southeast Connection [Member]	Mar. 31, 2014 Sabal Trail Transmission, LLC [Member] Corporate and Other [Member]	Mar. 31, 2014 Sabal Trail and Florida Southeast Connection [Member] FPL [Member] Natural Gas, Including Transportation And Storage, Contract Minimum Payments [Member]
Long-term Commitment (Excluding Unconditional Purchase Obligation) [Abstract]
Minimum annual purchase commitments (in megawatts)					1,330	375
Time period under contracts					through 2015	through 2021																	25-year
Minimum total purchase commitments (in megawatts)							705
Expiration dates of purchase commitments							2024 through 2034	through 2036											June 2014	October 2014	2030	2033
Equity Method Investment, Ownership Percentage																								33.00%
Long Term Purchase Commiment, Initial Quantity Per Day																							400,000
Long Term Purchase Commitment, Increased Volume Required																							600,000
Commitment amount included in capital expenditures		$ 2,400,000,000
Required capacity and/or minimum payments [Abstract]
Remainder of 2014	1,590,000,000								210,000,000	[1]	165,000,000	[1]	1,485,000,000	[2],[3]	50,000,000	[2]	130,000,000	[4],[5]
2015	600,000,000								290,000,000	[1]	195,000,000	[1]	855,000,000	[2],[3]	40,000,000	[2]	250,000,000	[4],[5]
2016	175,000,000								250,000,000	[1]	70,000,000	[1]	685,000,000	[2],[3]	20,000,000	[2]	515,000,000	[4],[5]
2017	105,000,000								255,000,000	[1]	50,000,000	[1]	745,000,000	[2],[3]	0	[2]	50,000,000	[4],[5]							200,000,000
2018	105,000,000								260,000,000	[1]	10,000,000	[1]	825,000,000	[2],[3]	0	[2]	25,000,000	[4],[5]							295,000,000
Thereafter	475,000,000								1,965,000,000	[1]	5,000,000	[1]	14,520,000,000	[2],[3]	0	[2]	50,000,000	[4],[5]							8,535,000,000
Capacity payments			123,000,000	126,000,000
Energy payments			56,000,000	23,000,000
Commitment to invest																	50,000,000
Joint Obligations of NEECH and NEER Included in NEER Amounts, remainder of current year																	320,000,000
Joint Obligations Of NEECH and NEER included NEER Amounts due in the second year																	$ 200,000,000

[1] Capacity charges under these contracts, substantially all of which are recoverable through the capacity cost recovery clause, totaled approximately $123 million and $126 million for the three months ended March 31, 2014 and 2013, respectively. Energy charges under these contracts, which are recoverable through the fuel clause, totaled approximately $56 million and $23 million for the three months ended March 31, 2014 and 2013, respectively

[2] Recoverable through the fuel clause.

[3] Includes approximately $200 million, $295 million and $8,535 million in 2017, 2018 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.

[4] Excludes approximately $320 million and $200 million in 2014 and 2015, respectively, of joint obligations of NEECH and NEER which are included in the NEER amounts above.

[5] Includes an approximately $50 million commitment to invest in clean power and technology businesses through 2021.

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Debt (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014
Capital Holdings [Member] | Debentures [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.70%	[1]
Principal Amount	$ 350
NextEra Energy Resources subsidiary [Member] | Canadian revolving credit agreements [Member]
Debt Instrument [Line Items]
Interest Rate Terms	Variable	[2]
Proceeds from Issuance of Debt	245
NextEra Energy Resources subsidiary [Member] | senior secured limited-recourse term loan due 2019 [Member]
Debt Instrument [Line Items]
Interest Rate Terms	Variable	[2]
Principal Amount	$ 44

[1] An interest rate swap agreement has been entered into with respect to this issuance. See Note 2.

[2] Variable rate is based on an underlying index plus a margin.

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Derivative Instruments (Net Notional Volumes and Additional Disclosures) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2014 MWh	Dec. 31, 2013 MWh
Commodity contract - Power [Member]
Derivative [Line Items]
Non-monetary net notional volumes	(111,000,000)	(276,000,000)
Commodity contract - Natural gas [Member]
Derivative [Line Items]
Non-monetary net notional volumes	1,333,000,000	1,140,000,000
Commodity contract - Oil [Member]
Derivative [Line Items]
Non-monetary net notional volumes	(9,000,000)	(10,000,000)
Interest rate contracts [Member]
Derivative [Line Items]
Notional amount	$ 6,800	$ 6,500
Currency Swap [Member]
Derivative [Line Items]
Notional amount	$ 662	$ 662
FPL [Member] | Commodity contract - Power [Member]
Derivative [Line Items]
Non-monetary net notional volumes	0	0
FPL [Member] | Commodity contract - Natural gas [Member]
Derivative [Line Items]
Non-monetary net notional volumes	937,000,000	674,000,000
FPL [Member] | Commodity contract - Oil [Member]
Derivative [Line Items]
Non-monetary net notional volumes	0	0

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Debt (Tables)

3 Months Ended

Mar. 31, 2014

Debt Disclosure [Abstract]

Long-term debt issuances and borrowings

Significant long-term debt issuances and borrowings by subsidiaries of NEE during the three months ended March 31, 2014 were as follows:

Date Issued	Company	Debt Issuances/Borrowings	Interest Rate			Principal Amount		Maturity Date
						(millions)
January - March 2014	NEER subsidiary	Canadian revolving credit agreements	Variable		(a)	$	245	Various
January 2014	NEER subsidiary	Senior secured limited-recourse term loan	Variable		(a)	$	44	2019
March 2014	NEECH	Debentures	2.700	%	(b)	$	350	2019

————————————

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

(b) An interest rate swap agreement has been entered into with respect to this issuance.  See Note 2.

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Commitments and Contingencies (Insurance and Legal Proceedings) (Details) (USD $)	3 Months Ended	24 Months Ended
	Mar. 31, 2014	Dec. 31, 1996	Oct. 31, 2004	Jan. 29, 1999
Insurance [Abstract]
Maximum obtainable amount of private liability insurance available under Price-Anderson Act	$ 375,000,000
Amount of secondary financial protection liability insurance coverage per incident	13,200,000,000
Potential Retrospective Assessments Under Secondary Financial Protection System	1,000,000,000
Potential Retrospective Assessments Under Secondary Financial Protection System Payable Per Incident Per Year	152,000,000
Amount of coverage per occurrence per site for property damage, decontamination and premature decommissioning risks	2,750,000,000
Amount of sublimit for nonnuclear perils per occurence per site under nuclear inusurance mutal companies for property damage decontamination and premature decommissioning risks	1,500,000,000
Potential amount of retrospective assessment per occurrence per site for property damage, decontamination and premature decommissioning risks	175,000,000
Legal Proceedings [Abstract]
FPL's interest owned in generation facility Scherer Unit No. 4	76.00%
Maximum amount of civil penalties per day - Clean Air Act from June 1, 1975 through January 30, 1997	25,000
Maximum amount of civil penalties per day - Clean Air Act from January 31, 1997 through March 15, 2004	27,500
Maximum amount of civil penalties per day - Clean Air Act from March 16, 2004 through January 12, 2009	32,500
Maximum amount of civil penalties per day - Clean Air Act from January 13, 2009 forward	37,500
Shares of Adelphia common stock purchased (in shares)		1,091,524
Shares of Adelphia preferred stock purchased (in shares)		20,000
Shares of Adelphia common stock if Adelphia preferred stock converted to Adelphia common stock (in shares)		2,358,490
Aggregate price paid for Adelphia common and preferred stock		35,900,000
Cash paid by Adelphia for repurchase of Adelphia acquired shares				149,213,130
Damages asserted for breach of contract			34,000,000
Seabrook Station Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for nuclear liability secondary financial protection	15,000,000
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	2,000,000
Duane Arnold Energy Center Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for nuclear liability secondary financial protection	38,000,000
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	5,000,000
St Lucie Unit No 2 Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for nuclear liability secondary financial protection	19,000,000
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	4,000,000
FPL [Member]
Insurance [Abstract]
Potential Retrospective Assessments Under Secondary Financial Protection System	509,000,000
Potential Retrospective Assessments Under Secondary Financial Protection System Payable Per Incident Per Year	76,000,000
Potential amount of retrospective assessment per occurrence per site for property damage, decontamination and premature decommissioning risks	$ 106,000,000

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Discontinued Operations (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Sale of hydropower generation plants through assumption of debt by buyer	$ 0	$ 700
Maine Hydro [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Capacity associated with discontinued operations (in megawatts)		351
Sale of hydropower generation plants through assumption of debt by buyer		700
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax		372
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax		$ 231

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Fair Value Measurements (Reconciliation of Changes in the Fair Value of Derivatives) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013
Realized and unrealized gains (losses): [Abstract]
Realized and unrealized gains (losses) reflected in operating revenues	$ (405)		$ (1)
Realized and unrealized gains (losses) reflected in interest expense	(15)
Unrealized gains (losses) reflected in operating revenues related to derivatives still held at the reporting date	(234)		31
Derivative Financial Instruments, Net [Member]
Reconciliation of changes in the fair value of derivatives measured based on significant unobservable inputs Roll Forward [Abstract]
Fair value of net derivatives based on significant unobservable inputs, beginning balance	622		566
Realized and unrealized gains (losses): [Abstract]
Included in Earnings	(423)	[1]	(3)	[1]
Included in regulatory assets and liabilities	4		1
Purchases	4		49
Settlements	266		(33)
Issuances	(19)		(64)
Transfers in	7	[2]	0	[2]
Transfers out	(1)	[2]	6	[2]
Fair value of net derivatives based on significant unobservable inputs, ending balance	460		522
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	(249)	[3]	32	[3]
FPL [Member] | Derivative Financial Instruments, Net [Member]
Reconciliation of changes in the fair value of derivatives measured based on significant unobservable inputs Roll Forward [Abstract]
Fair value of net derivatives based on significant unobservable inputs, beginning balance	0		2
Realized and unrealized gains (losses): [Abstract]
Included in Earnings	0		0
Included in regulatory assets and liabilities	4		1
Purchases	0		0
Settlements	(1)		(1)
Issuances	0		0
Transfers in	0		0
Transfers out	0		0
Fair value of net derivatives based on significant unobservable inputs, ending balance	3		2
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	$ 0		$ 0

[1] For the three months ended March 31, 2014, realized and unrealized losses of approximately $405 million are reflected in the condensed consolidated statements of income in operating revenues, $15 million in interest expense and the balance is reflected in fuel, purchased power and interchange. For the three months ended March 31, 2013, realized and unrealized losses are reflected in the condensed consolidated statements of income in fuel, purchased power and interchange.

[2] Transfers into Level 3 were a result of decreased observability of market data and transfers from Level 3 to Level 2 were a result of increased observability of market data. NEE's and FPL's policy is to recognize all transfers at the beginning of the reporting period.

[3] For the three months ended March 31, 2014, unrealized losses of $234 million are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in interest expense. For the three months ended March 31, 2013, unrealized gains of approximately $31 million are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

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Summarized Financial Information of Capital Holdings (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013		Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
NEECH a 100% owned subsidiary of NEE	100.00%
Condensed Consolidating Statements of Income
Operating revenues	$ 3,674		$ 3,279
Operating expenses	(2,936)		(2,845)
Interest expense	(319)		(272)
Equity in earnings of subsidiaries	0		0
Other income (deductions) - net	164		23	[1]
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	583		185	[1]
Income tax expense (benefit)	153		144	[1]
Income (loss) from continuing operations	430		41	[1],[2]
GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	0		231	[1],[2],[3]
Net income (loss)	430		272
COMPREHENSIVE INCOME	395		391
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	70,367				69,448
Less accumulated depreciation and amortization	(17,061)				(16,728)
Total property, plant and equipment - net	53,306				52,720
CURRENT ASSETS
Cash and cash equivalents	488		215
Receivables	2,551				2,289
Other	3,102				3,115
Total current assets	6,141				5,842
OTHER ASSETS
Investment in subsidiaries	0				0
Other	10,884				10,744
Total other assets	10,884				10,744
TOTAL ASSETS	70,331				69,306
CAPITALIZATION
Common shareholders' equity	18,160				18,040
Long-term debt	23,824				23,969
Total capitalization	41,984				42,009
CURRENT LIABILITIES
Debt due within one year	5,691				4,457
Accounts payable	1,450				1,200
Other	3,151				3,532
Total current liabilities	10,292				9,189
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,877				1,850
Deferred income taxes	8,306				8,144
Other	7,872				8,114
Total other liabilities and deferred credits	18,055				18,108
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	70,331				69,306
Condensed Consolidating Statements of Cash Flows
NET CASH PROVIDED BY OPERATING ACTIVITIES	1,017		1,082
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	(1,866)		(1,867)
Capital contribution to FPL	0		0
Cash grants under the Recovery Act	0		170
Change in loan proceeds restricted for construction	(28)		112
Other - net	52		7
Net cash used in investing activities	(1,842)		(1,578)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	655		623
Retirements of long-term debt	(717)		(923)
Net change in short-term debt	1,179		966
Issuances of common stock	25		8
Dividends on common stock	(315)		(279)
Other Financing Activities, Not Otherwise Separately Disclosed	73		(5)
Proceeds from (Payments for) Other Financing Activities	70		7
Net cash provided by (used in) financing activities	875		382
Net increase (decrease) in cash and cash equivalents	50		(114)
Cash and cash equivalents at beginning of period	438		329
Cash and cash equivalents at end of period	488		215
NextEra Energy (Guarantor) [Member]
Condensed Consolidating Statements of Income
Operating revenues	0		0
Operating expenses	(4)		(3)
Interest expense	(2)		(2)
Equity in earnings of subsidiaries	435		249
Other income (deductions) - net	1		(2)	[1]
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	430		242	[1]
Income tax expense (benefit)	0		(15)
Income (loss) from continuing operations	430		257	[1]
GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	0		15	[1]
Net income (loss)	430		272
COMPREHENSIVE INCOME	395		391
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	31				31
Less accumulated depreciation and amortization	(11)				(10)
Total property, plant and equipment - net	20				21
CURRENT ASSETS
Cash and cash equivalents	5		0
Receivables	121				78
Other	210				6
Total current assets	336				84
OTHER ASSETS
Investment in subsidiaries	17,962				17,910
Other	764				694
Total other assets	18,726				18,604
TOTAL ASSETS	19,082				18,709
CAPITALIZATION
Common shareholders' equity	18,160				18,040
Long-term debt	0				0
Total capitalization	18,160				18,040
CURRENT LIABILITIES
Debt due within one year	0				0
Accounts payable	0				0
Other	390				199
Total current liabilities	390				199
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	0				0
Deferred income taxes	251				166
Other	281				304
Total other liabilities and deferred credits	532				470
TOTAL CAPITALIZATION AND LIABILITIES	19,082				18,709
Condensed Consolidating Statements of Cash Flows
NET CASH PROVIDED BY OPERATING ACTIVITIES	428		350
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	0		0
Capital contribution to FPL	(100)		0
Cash grants under the Recovery Act	0		0
Change in loan proceeds restricted for construction	0		0
Other - net	0		(52)
Net cash used in investing activities	(100)		(52)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	0		0
Retirements of long-term debt	0		0
Net change in short-term debt	0		0
Dividends on common stock	(315)		(279)
Proceeds from (Payments for) Other Financing Activities	(8)		(21)
Net cash provided by (used in) financing activities	(323)		(300)
Net increase (decrease) in cash and cash equivalents	5		(2)
Cash and cash equivalents at beginning of period	0		2
Cash and cash equivalents at end of period	5		0
Capital Holdings Consolidated [Member]
Condensed Consolidating Statements of Income
Operating revenues	1,142		1,094
Operating expenses	(1,032)		(1,200)
Interest expense	(216)		(170)
Equity in earnings of subsidiaries	0		0
Other income (deductions) - net	148		5	[1]
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	42		(271)	[1]
Income tax expense (benefit)	(46)		(16)	[1]
Income (loss) from continuing operations	88		(255)	[1]
GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	0		216	[1]
Net income (loss)	88		(39)
COMPREHENSIVE INCOME	48		73
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	29,634				29,511
Less accumulated depreciation and amortization	(5,965)				(5,774)
Total property, plant and equipment - net	23,669				23,737
CURRENT ASSETS
Cash and cash equivalents	445		179
Receivables	2,107				1,542
Other	1,623				1,814
Total current assets	4,175				3,774
OTHER ASSETS
Investment in subsidiaries	0				0
Other	5,129				5,129
Total other assets	5,129				5,129
TOTAL ASSETS	32,973				32,640
CAPITALIZATION
Common shareholders' equity	4,432				4,816
Long-term debt	15,381				15,496
Total capitalization	19,813				20,312
CURRENT LIABILITIES
Debt due within one year	5,009				3,896
Accounts payable	758				589
Other	1,864				2,203
Total current liabilities	7,631				6,688
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	575				565
Deferred income taxes	1,982				1,963
Other	2,972				3,112
Total other liabilities and deferred credits	5,529				5,640
TOTAL CAPITALIZATION AND LIABILITIES	32,973				32,640
Condensed Consolidating Statements of Cash Flows
NET CASH PROVIDED BY OPERATING ACTIVITIES	147		295
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	(798)		(1,046)
Capital contribution to FPL	0		0
Cash grants under the Recovery Act	0		170
Change in loan proceeds restricted for construction	(28)		112
Other - net	58		29
Net cash used in investing activities	(768)		(735)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	655		623
Retirements of long-term debt	(688)		(496)
Net change in short-term debt	1,059		166
Dividends on common stock	0		0
Proceeds from (Payments for) Other Financing Activities	(378)		39
Net cash provided by (used in) financing activities	648		332
Net increase (decrease) in cash and cash equivalents	27		(108)
Cash and cash equivalents at beginning of period	418		287
Cash and cash equivalents at end of period	445		179
Other Consolidated Entity And Consolidation Eliminations [Member]
Condensed Consolidating Statements of Income
Operating revenues	2,532	[4]	2,185	[4]
Operating expenses	(1,900)	[4]	(1,642)	[4]
Interest expense	(101)	[4]	(100)	[4]
Equity in earnings of subsidiaries	(435)	[4]	(249)	[4]
Other income (deductions) - net	15	[4]	20	[1],[4]
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	111	[4]	214	[1],[4]
Income tax expense (benefit)	199	[4]	175	[1],[4]
Income (loss) from continuing operations	(88)	[4]	39	[4]
GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	0	[4]	0	[4]
Net income (loss)	(88)	[4]	39	[4]
COMPREHENSIVE INCOME	(48)	[4]	(73)	[4]
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	40,702	[4]			39,906	[4]
Less accumulated depreciation and amortization	(11,085)	[4]			(10,944)	[4]
Total property, plant and equipment - net	29,617	[4]			28,962	[4]
CURRENT ASSETS
Cash and cash equivalents	38	[4]	36	[4]
Receivables	323	[4]			669	[4]
Other	1,269	[4]			1,295	[4]
Total current assets	1,630	[4]			1,984	[4]
OTHER ASSETS
Investment in subsidiaries	(17,962)	[4]			(17,910)	[4]
Other	4,991	[4]			4,921	[4]
Total other assets	(12,971)	[4]			(12,989)	[4]
TOTAL ASSETS	18,276	[4]			17,957	[4]
CAPITALIZATION
Common shareholders' equity	(4,432)	[4]			(4,816)	[4]
Long-term debt	8,443	[4]			8,473	[4]
Total capitalization	4,011	[4]			3,657	[4]
CURRENT LIABILITIES
Debt due within one year	682	[4]			561	[4]
Accounts payable	692	[4]			611	[4]
Other	897	[4]			1,130	[4]
Total current liabilities	2,271	[4]			2,302	[4]
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,302	[4]			1,285	[4]
Deferred income taxes	6,073	[4]			6,015	[4]
Other	4,619	[4]			4,698	[4]
Total other liabilities and deferred credits	11,994	[4]			11,998	[4]
TOTAL CAPITALIZATION AND LIABILITIES	18,276	[4]			17,957	[4]
Condensed Consolidating Statements of Cash Flows
NET CASH PROVIDED BY OPERATING ACTIVITIES	442	[4]	437	[4]
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	(1,068)	[4]	(821)	[4]
Capital contribution to FPL	100	[4]	0	[4]
Cash grants under the Recovery Act	0	[4]	0	[4]
Change in loan proceeds restricted for construction	0	[4]	0	[4]
Other - net	(6)	[4]	30	[4]
Net cash used in investing activities	(974)	[4]	(791)	[4]
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	0	[4]	0	[4]
Retirements of long-term debt	(29)	[4]	(427)	[4]
Net change in short-term debt	120	[4]	800	[4]
Dividends on common stock	0	[4]	0	[4]
Proceeds from (Payments for) Other Financing Activities	459	[4]	(23)	[4]
Net cash provided by (used in) financing activities	550	[4]	350	[4]
Net increase (decrease) in cash and cash equivalents	18	[4]	(4)	[4]
Cash and cash equivalents at beginning of period	20	[4]	40	[4]
Cash and cash equivalents at end of period	$ 38	[4]	$ 36	[4]

[1] Certain amounts were restated to conform to current year's presentation. See Note 3 - Nonrecurring Fair Value Measurements

[2] (c)Prior year amounts were restated to conform to current year's presentation. See Note 3 - Nonrecurring Fair Value Measurements.

[3] See Note 5.

[4] Represents FPL and consolidating adjustments.

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Commitments and Contingencies (Planned Capital Expenditures) (Details) (USD $)	3 Months Ended
	Mar. 31, 2014 MW
FPL [Member]
Planned Capital Expenditures [Line Items]
Remainder Current Year	$ 2,305,000,000	[1]
2015	2,540,000,000	[1]
2016	2,145,000,000	[1]
2017	1,890,000,000	[1]
2018	1,910,000,000	[1]
Total	10,790,000,000	[1]
Incremental Capital Expenditures Low Range	1,500,000,000
Incremental Capital Expenditures High Range	2,500,000,000
FPL [Member] | New Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
Remainder Current Year	475,000,000	[2],[3],[4]
2015	295,000,000	[2],[3],[4]
2016	70,000,000	[2],[3],[4]
2017	0	[2],[3],[4]
2018	0	[2],[3],[4]
Total	840,000,000	[2],[3],[4]
FPL [Member] | Existing Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
Remainder Current Year	565,000,000	[2]
2015	680,000,000	[2]
2016	610,000,000	[2]
2017	580,000,000	[2]
2018	545,000,000	[2]
Total	2,980,000,000	[2]
FPL [Member] | Transmission And Distribution Expenditures [Member]
Planned Capital Expenditures [Line Items]
Remainder Current Year	1,055,000,000
2015	1,200,000,000
2016	1,125,000,000
2017	955,000,000
2018	1,025,000,000
Total	5,360,000,000
FPL [Member] | Nuclear Fuel Expenditures [Member]
Planned Capital Expenditures [Line Items]
Remainder Current Year	80,000,000
2015	210,000,000
2016	220,000,000
2017	190,000,000
2018	180,000,000
Total	880,000,000
FPL [Member] | General And Other Expenditures [Member]
Planned Capital Expenditures [Line Items]
Remainder Current Year	130,000,000
2015	155,000,000
2016	120,000,000
2017	165,000,000
2018	160,000,000
Total	730,000,000
FPL [Member] | Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
Allowance for funds used during construction (AFUDC) - remainder of 2014	28,000,000
Allowance for funds used during construction (AFUDC) - 2015	53,000,000
Allowance for funds used during construction (AFUDC) - 2016	17,000,000
NextEra Energy Resources [Member]
Planned Capital Expenditures [Line Items]
Remainder Current Year	2,595,000,000
2015	1,655,000,000
2016	915,000,000
2017	305,000,000
2018	355,000,000
Total	5,825,000,000
NextEra Energy Resources [Member] | Wind Expenditures [Member]
Planned Capital Expenditures [Line Items]
Remainder Current Year	1,505,000,000	[5]
2015	610,000,000	[5]
2016	25,000,000	[5]
2017	10,000,000	[5]
2018	15,000,000	[5]
Total	2,165,000,000	[5]
Planned New Wind Generation To Be Added over 5 Years (in megawatts)	1,815
Planned new wind generation added to date (in megawatts)	325
NextEra Energy Resources [Member] | Wind Expenditures [Member] | CANADA
Planned Capital Expenditures [Line Items]
Planned New Wind Generation To Be Added over 5 Years (in megawatts)	465
NextEra Energy Resources [Member] | Wind Expenditures [Member] | Minimum [Member]
Planned Capital Expenditures [Line Items]
Expected New Wind Projects, Three-Year Period, Capacity	2,000
Expected New Wind Projects, Three-Year Period, Expected Costs	3,500,000,000
NextEra Energy Resources [Member] | Wind Expenditures [Member] | Maximum [Member]
Planned Capital Expenditures [Line Items]
Expected New Wind Projects, Three-Year Period, Capacity	2,500
Expected New Wind Projects, Three-Year Period, Expected Costs	4,500,000,000
NextEra Energy Resources [Member] | Solar Expenditures [Member]
Planned Capital Expenditures [Line Items]
Remainder Current Year	480,000,000	[6]
2015	750,000,000	[6]
2016	520,000,000	[6]
2017	0	[6]
2018	0	[6]
Total	1,750,000,000	[6]
Planned new solar generation over 5 year period (in megawatts)	600
Equity Method Investment, Ownership Percentage	50.00%
Planned New Solar Capacity of Equity Method Investment (in megawatts)	550
NextEra Energy Resources [Member] | Solar Expenditures [Member] | Expected to Close Mid 2014 [Member]
Planned Capital Expenditures [Line Items]
Planned new solar generation over 5 year period (in megawatts)	250
Planned New Solar Generation Over Five Year Period, Expected Costs	1,000,000,000
NextEra Energy Resources [Member] | Solar Expenditures [Member] | Requiring Internal Approvals [Member]
Planned Capital Expenditures [Line Items]
Planned new solar generation over 5 year period (in megawatts)	47
Planned New Solar Generation Over Five Year Period, Expected Costs	120,000,000
NextEra Energy Resources [Member] | Nuclear Expenditures [Member]
Planned Capital Expenditures [Line Items]
Remainder Current Year	265,000,000	[7]
2015	275,000,000	[7]
2016	295,000,000	[7]
2017	255,000,000	[7]
2018	265,000,000	[7]
Total	1,355,000,000	[7]
NextEra Energy Resources [Member] | Other Expenditures [Member]
Planned Capital Expenditures [Line Items]
Remainder Current Year	345,000,000	[8]
2015	20,000,000	[8]
2016	75,000,000	[8]
2017	40,000,000	[8]
2018	75,000,000	[8]
Total	555,000,000	[8]
Corporate and Other [Member]
Planned Capital Expenditures [Line Items]
Remainder Current Year	190,000,000	[9]
2015	445,000,000	[9]
2016	795,000,000	[9]
2017	225,000,000	[9]
2018	95,000,000	[9]
Total	1,750,000,000	[9]
Corporate and Other [Member] | Natural Gas Expenditures [Member]
Planned Capital Expenditures [Line Items]
Allowance for funds used during construction (AFUDC) - remainder of 2014	1,000,000
Allowance for funds used during construction (AFUDC) - 2015	7,000,000
Allowance for funds used during construction (AFUDC) - 2016	20,000,000
Allowance for funds used during construction (AFUDC) - 2017	12,000,000
Potential Capital Expenditures For Natural Gas Pipeline	1,400,000,000
Sabal Trail Transmission, LLC [Member] | Corporate and Other [Member] | Natural Gas Expenditures [Member]
Planned Capital Expenditures [Line Items]
Equity method investment in natural gas pipeline, through 2018	885,000,000
Sabal Trail Transmission, LLC [Member] | Corporate and Other [Member]
Planned Capital Expenditures [Line Items]
Equity Method Investment, Ownership Percentage	33.00%
Florida Southeast Connection, LLC [Member] | Corporate and Other [Member] | Natural Gas Expenditures [Member]
Planned Capital Expenditures [Line Items]
Planned capital expenditures for natural gas pipeline	$ 525,000,000

[1] FPL has identified $1.5 billion to $2.5 billion in potential incremental capital expenditures through 2016 in addition to what is included in the table above.

[2] Includes allowance for funds used during construction (AFUDC) of approximately $28 million, $53 million and $17 million for the remainder of 2014 through 2016, respectively.

[3] Consists of projects that have received FPSC approval. Excludes capital expenditures for the construction costs for the two additional nuclear units at FPL's Turkey Point site beyond what is required to receive an NRC license for each unit.

[4] Includes land, generating structures, transmission interconnection and integration and licensing.

[5] Consists of capital expenditures for new wind projects and related transmission totaling approximately 1,815 MW, including approximately 465 MW in Canada, that have received applicable internal approvals. NEER expects to add new U.S. wind generation of 2,000 MW to 2,500 MW in 2013 through 2015, including 325 MW added to date, at a total cost of up to $3.5 billion to $4.5 billion.

[6] Consists of capital expenditures for new solar projects and related transmission totaling approximately 600 MW that have received applicable internal approvals, including equity contributions associated with a 50% equity investment in a 550 MW solar project. Includes approximately $1 billion of total estimated costs associated with the pending acquisition of the development rights for a 250 MW solar project that is expected to close in mid-2014, subject to certain conditions precedent, and construction of the project, which is expected to be completed in 2016. Excludes solar projects requiring internal approvals with generation totaling 47 MW with an estimated cost of approximately $120 million.

[7] Includes nuclear fuel.

[8] Consists of capital expenditures that have received applicable internal approvals.

[9] Includes capital expenditures totaling approximately $1.4 billion for the remainder of 2014 through 2018 for construction of a natural gas pipeline system that has received applicable internal approvals, including approximately $885 million of equity contributions associated with a 33% equity investment in the northern portion of the natural gas pipeline system and $525 million for the southern portion, which includes AFUDC of approximately $1 million, $7 million, $20 million and $12 million for the remainder of 2014 through 2017, respectively. The natural gas pipeline system is subject to certain conditions, including FERC approval. A FERC decision is expected in 2015. See Contracts below.

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Derivative Instruments

3 Months Ended

Mar. 31, 2014

Derivative Instruments and Hedging Activities Disclosure [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 with outstanding and forecasted debt issuances, 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 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 the commodity price risk associated with the fuel requirements of the assets, where applicable, as well as 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 the 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 condensed 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 other - net in NEE's condensed consolidated statements of income.  Settlement gains and losses are included within the line items in the condensed 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 condensed 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 condensed consolidated statements of cash flows.

While most of NEE's derivatives are entered into for the purpose of managing commodity price risk, optimizing the value of NEER's power generation and gas infrastructure assets, reducing the impact of volatility in interest rates on outstanding and forecasted debt issuances and managing foreign currency risk, hedge accounting is only applied where specific criteria are met and it is practicable to do so.  In order to apply hedge accounting, the transaction must be designated as a hedge and it must be highly effective in offsetting the hedged risk.  Additionally, for hedges of forecasted transactions, the forecasted transactions must be probable.  For interest rate and foreign currency derivative instruments, generally NEE assesses a hedging instrument's effectiveness by using nonstatistical methods including dollar value comparisons of the change in the fair value of the derivative to the change in the fair value or cash flows of the hedged item.  Hedge effectiveness is tested at the inception of the hedge and on at least a quarterly basis throughout its life.  The effective portion of the gain or loss on a derivative instrument designated as a cash flow hedge is reported as a component of other comprehensive income (OCI) and is reclassified into earnings in the period(s) during which the transaction being hedged affects earnings or when it becomes probable that a forecasted transaction being hedged would not occur.  The ineffective portion of net unrealized gains (losses) on these hedges is reported in earnings in the current period.  In April 2013, NEE discontinued hedge accounting for cash flow hedges related to interest rate swaps associated with the solar projects in Spain (see Note 9 - Spain Solar Projects).  At March 31, 2014, NEE's accumulated other comprehensive income (AOCI) included amounts related to interest rate cash flow hedges with expiration dates through June 2031 and foreign currency cash flow hedges with expiration dates through September 2030.  Approximately $61 million of net losses included in AOCI at March 31, 2014 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 interest rates, currency exchange rates or scheduled principal payments.

Fair Value of Derivative Instruments - The tables below present NEE's and FPL's gross derivative positions at March 31, 2014 and December 31, 2013, 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 3 - Recurring Fair Value Measurements for netting information), as well as the location of the net derivative position on the condensed consolidated balance sheets.

	March 31, 2014
	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	$	—	$	—	$	4,553	$	3,705	$	1,441	$	834
Interest rate contracts	76		125		—		108		76		233
Foreign currency swaps	—		49		—		95		—		144
Total fair values	$	76	$	174	$	4,553	$	3,908	$	1,517	$	1,211
FPL:
Commodity contracts	$	—	$	—	$	123	$	3	$	130	$	10
Net fair value by NEE balance sheet line item:
Current derivative assets(a)									$	533
Noncurrent derivative assets(b)									984
Current derivative liabilities											$	815
Noncurrent derivative liabilities(c)											396
Total derivatives									$	1,517	$	1,211
Net fair value by FPL balance sheet line item:
Current other assets									$	129
Noncurrent other assets									1
Noncurrent other liabilities											$	10
Total derivatives									$	130	$	10

______________________

(a) Reflects the netting of approximately $165 million in margin cash collateral received from counterparties.

(b) Reflects the netting of approximately $88 million in margin cash collateral received from counterparties.

(c) Reflects the netting of approximately $12 million in margin cash collateral provided to counterparties.

	December 31, 2013
	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	$	—	$	—	$	4,543	$	3,633	$	1,571	$	940
Interest rate contracts	89		127		1		93		90		220
Foreign currency swaps	—		50		—		101		—		151
Total fair values	$	89	$	177	$	4,544	$	3,827	$	1,661	$	1,311
FPL:
Commodity contracts	$	—	$	—	$	55	$	9	$	48	$	2
Net fair value by NEE balance sheet line item:
Current derivative assets(a)									$	498
Noncurrent derivative assets(b)									1,163
Current derivative liabilities											$	838
Noncurrent derivative liabilities											473
Total derivatives									$	1,661	$	1,311
Net fair value by FPL balance sheet line item:
Current other assets									$	48
Current other liabilities											$	1
Noncurrent other liabilities											1
Total derivatives									$	48	$	2

______________________

(a) Reflects the netting of approximately $181 million in margin cash collateral received from counterparties.

(b) Reflects the netting of approximately $98 million in margin cash collateral received from counterparties.

At March 31, 2014 and December 31, 2013, NEE had approximately $45 million and $24 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 condensed consolidated balance sheets.  Additionally, at March 31, 2014 and December 31, 2013, NEE had approximately $109 million and $42 million (none at FPL), respectively, in margin cash collateral provided 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 condensed consolidated balance sheets.

Income Statement Impact of Derivative Instruments - Gains (losses) related to NEE's cash flow hedges are recorded in NEE's condensed consolidated financial statements (none at FPL) as follows:

	Three Months Ended March 31,
	2014											2013
	Interest Rate Contracts				Foreign Currency Swaps				Total			Interest Rate Contracts				Foreign Currency Swaps				Total
	(millions)
Gains (losses) recognized in OCI	$	(27	)		$	(2	)		$	(29	)	$	100			$	(8	)		$	92
Gains (losses) reclassified from AOCI to net income	$	(16	)	(a)	$	2		(b)	$	(14	)	$	(15	)	(a)	$	(19	)	(b)	$	(34	)

————————————

(a) Included in interest expense.

(b) Loss of approximately $1 million is included in interest expense and the balance is included in other - net.

For the three months ended March 31, 2014 and 2013, NEE recorded a gain of approximately $4 million and a loss of $9 million, respectively, on fair value hedges which resulted in a corresponding increase and decrease, respectively, in the related debt.

Gains (losses) related to NEE's derivatives not designated as hedging instruments are recorded in NEE's condensed consolidated statements of income as follows:

	Three Months Ended   March 31,
	2014			2013
	(millions)
Commodity contracts:(a)
Operating revenues	$	(272	)	$	(42	)
Fuel, purchased power and interchange	(4		)	3
Foreign currency swap - other - net	5			(32		)
Interest rate contracts - interest expense	(27		)	—
Total	$	(298	)	$	(71	)

————————————

(a) For the three months ended March 31, 2014 and 2013, FPL recorded approximately $136 million and $144 million of gains, respectively, related to commodity contracts as regulatory liabilities on its condensed 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 condensed 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:

	March 31, 2014					December 31, 2013
Commodity Type	NEE			FPL		NEE			FPL
	(millions)
Power	(111	)	MWh(a)	—		(276	)	MWh(a)	—
Natural gas	1,333		MMBtu(b)	937	MMBtu(b)	1,140		MMBtu(b)	674	MMBtu(b)
Oil	(9	)	barrels	—		(10	)	barrels	—

————————————

(a) Megawatt-hours

(b) One million British thermal units

At March 31, 2014 and December 31, 2013, NEE had interest rate contracts with a notional amount totaling approximately $6.8 billion and $6.5 billion, respectively, and foreign currency swaps with a notional amount totaling approximately $662 million and $662 million, respectively.

Credit-Risk-Related ContingentFeatures - 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 March 31, 2014 and December 31, 2013, the aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately $1.8 billion ($4 million for FPL) and $2.1 billion ($9 million for FPL), respectively.

If the credit-risk-related contingent features underlying these agreements and other commodity-related contracts 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 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 $300 million ($20 million at FPL) as of March 31, 2014 and $400 million ($20 million at FPL) as of December 31, 2013.If FPL's and NEECH's credit ratings were downgraded to below investment grade, applicable NEE subsidiaries would be required to post additional collateral such that the total posted collateral would be approximately $2.2 billion ($0.4 billion at FPL) and $2.3 billion ($0.4 billion at FPL) as of March 31, 2014 and December 31, 2013, respectively.  Some 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 $800 million ($200 million at FPL) and $800 million ($150 million at FPL) as of March 31, 2014 and December 31, 2013, respectively.

Collateral related to derivatives may be posted in the form of cash or credit support in the normal course of business.  At March 31, 2014 and December 31, 2013, applicable NEE subsidiaries have posted approximately $73 million (none at FPL) and $210 million (none at FPL), respectively, 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.

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Variable Interest Entities (VIEs) (Details) (USD $) In Millions, unless otherwise specified							3 Months Ended					3 Months Ended			3 Months Ended
	Mar. 31, 2014	Mar. 31, 2014 Other variable interest entities [Member]	Dec. 31, 2013 Other variable interest entities [Member]	Mar. 31, 2014 FPL [Member] Bankruptcy remote special purpose subsidiary [Member]	Dec. 31, 2013 FPL [Member] Bankruptcy remote special purpose subsidiary [Member]	Dec. 31, 2007 FPL [Member] Bankruptcy remote special purpose subsidiary [Member]	Mar. 31, 2014 FPL [Member] Qualifying facility 1 [Member] MWh MW	Mar. 31, 2013 FPL [Member] Qualifying facility 1 [Member] MWh	Mar. 31, 2014 FPL [Member] Qualifying facility 2 [Member] MW	Mar. 31, 2014 FPL [Member] Other variable interest entities [Member]	Dec. 31, 2013 FPL [Member] Other variable interest entities [Member]	Mar. 31, 2014 NextEra Energy Resources [Member]	Mar. 31, 2014 NextEra Energy Resources [Member] Gas and/or oil variable interest entities [Member] MW entities	Dec. 31, 2013 NextEra Energy Resources [Member] Gas and/or oil variable interest entities [Member]	Mar. 31, 2014 NextEra Energy Resources [Member] Wind variable interest entities [Member] MW entities	Dec. 31, 2013 NextEra Energy Resources [Member] Wind variable interest entities [Member]
Variable Interest Entity [Line Items]
Total number of consolidated variable interest entities	14											13	1		12	12
Storm-recovery bonds aggregate principal amount issued						$ 652
Proceeds from issuance of storm-recovery bonds						644
Carrying amount of assets, consolidated variable interest entity				290	324								90	85	5,200	5,300
Carrying amount of liabilities, consolidated variable interest entity				360	394								65	63	3,300	3,300
Coal fired generating facility capacity (in megawatts)							250		330
Quantity of electricity purchased (in megawatt-hours)							128,940	79,210
Cost of electricity purchased							36	35
Ownership percentage												100.00%
Natural gas and or oil electric generating facility capacity (in megawatts)													110
Expiration date of power sales contracts with third parties, low range													2018		2018
Expiration date of power sales contracts with third parties, high range													2020		2038
Wind electric generating facility capability (in megawatts)															3,541
Total number of consolidated VIEs sell electric output under power sales contracts															10
Total number of consolidated VIEs sell in spot market															2
Investments in special purpose entities		$ 700	$ 668							$ 541	$ 505

XML

Employee Retirement Benefits (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Pension Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Service cost	$ 16	$ 18
Interest cost	25	24
Expected return on plan assets	(60)	(60)
Amortization of prior service cost (benefit)	1	2
Amortization of losses	0	1
Net periodic benefit (income) cost	(18)	(15)
Other Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Service cost	1	1
Interest cost	4	4
Expected return on plan assets	0	0
Amortization of prior service cost (benefit)	(1)	(1)
Amortization of losses	0	1
Net periodic benefit (income) cost	4	5
FPL [Member] | Pension Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Net periodic benefit (income) cost	(11)	(10)
FPL [Member] | Other Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Net periodic benefit (income) cost	$ 3	$ 3

XML

Summarized Financial Information of Capital Holdings (Tables)

3 Months Ended

Mar. 31, 2014

Summarized Financial Information [Abstract]

Condensed Consolidating Statements

Condensed consolidating financial information is as follows:

Condensed Consolidating Statements of Income

	Three Months Ended March 31,
	2014												2013(a)
	NEE (Guarantor)			NEECH			Other(b)			NEE Consoli- dated			NEE (Guarantor)			NEECH			Other(b)			NEE Consoli- dated
										(millions)
Operating revenues	$	—		$	1,142		$	2,532		$	3,674		$	—		$	1,094		$	2,185		$	3,279
Operating expenses	(4		)	(1,032		)	(1,900		)	(2,936		)	(3		)	(1,200		)	(1,642		)	(2,845		)
Interest expense	(2		)	(216		)	(101		)	(319		)	(2		)	(170		)	(100		)	(272		)
Equity in earnings of subsidiaries	435			—			(435		)	—			249			—			(249		)	—
Other income (deductions) - net	1			148			15			164			(2		)	5			20			23
Income (loss) from continuing operations before income taxes	430			42			111			583			242			(271		)	214			185
Income tax expense (benefit)	—			(46		)	199			153			(15		)	(16		)	175			144
Income (loss) from continuing operations	430			88			(88		)	430			257			(255		)	39			41
Gain from discontinued operations, net of income taxes	—			—			—			—			15			216			—			231
Net income (loss)	$	430		$	88		$	(88	)	$	430		$	272		$	(39	)	$	39		$	272

————————————

(a)  Certain amounts were restated to conform to current year's presentation.  See Note 3 - Nonrecurring Fair Value Measurements.

(b)  Represents FPL and consolidating adjustments.

Condensed Consolidating Statements of Comprehensive Income

	Three Months Ended March 31,
	2014									2013
	NEE (Guarantor)		NEECH		Other(a)			NEE Consoli- dated		NEE (Guarantor)		NEECH		Other(a)			NEE Consoli- dated
								(millions)
Comprehensive income (loss)	$	395	$	48	$	(48	)	$	395	$	391	$	73	$	(73	)	$	391

————————————

(a) Represents FPL and consolidating adjustments.

Condensed Consolidating Balance Sheets

	March 31, 2014												December 31, 2013
	NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated			NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	$	31		$	29,634		$	40,702		$	70,367		$	31		$	29,511		$	39,906		$	69,448
Less accumulated depreciation and amortization	(11		)	(5,965		)	(11,085		)	(17,061		)	(10		)	(5,774		)	(10,944		)	(16,728		)
Total property, plant and equipment - net	20			23,669			29,617			53,306			21			23,737			28,962			52,720
CURRENT ASSETS
Cash and cash equivalents	5			445			38			488			—			418			20			438
Receivables	121			2,107			323			2,551			78			1,542			669			2,289
Other	210			1,623			1,269			3,102			6			1,814			1,295			3,115
Total current assets	336			4,175			1,630			6,141			84			3,774			1,984			5,842
OTHER ASSETS
Investment in subsidiaries	17,962			—			(17,962		)	—			17,910			—			(17,910		)	—
Other	764			5,129			4,991			10,884			694			5,129			4,921			10,744
Total other assets	18,726			5,129			(12,971		)	10,884			18,604			5,129			(12,989		)	10,744
TOTAL ASSETS	$	19,082		$	32,973		$	18,276		$	70,331		$	18,709		$	32,640		$	17,957		$	69,306
CAPITALIZATION
Common shareholders' equity	$	18,160		$	4,432		$	(4,432	)	$	18,160		$	18,040		$	4,816		$	(4,816	)	$	18,040
Long-term debt	—			15,381			8,443			23,824			—			15,496			8,473			23,969
Total capitalization	18,160			19,813			4,011			41,984			18,040			20,312			3,657			42,009
CURRENT LIABILITIES
Debt due within one year	—			5,009			682			5,691			—			3,896			561			4,457
Accounts payable	—			758			692			1,450			—			589			611			1,200
Other	390			1,864			897			3,151			199			2,203			1,130			3,532
Total current liabilities	390			7,631			2,271			10,292			199			6,688			2,302			9,189
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	—			575			1,302			1,877			—			565			1,285			1,850
Deferred income taxes	251			1,982			6,073			8,306			166			1,963			6,015			8,144
Other	281			2,972			4,619			7,872			304			3,112			4,698			8,114
Total other liabilities and deferred credits	532			5,529			11,994			18,055			470			5,640			11,998			18,108
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	19,082		$	32,973		$	18,276		$	70,331		$	18,709		$	32,640		$	17,957		$	69,306

————————————

(a) Represents FPL and consolidating adjustments.

Condensed Consolidating Statements of Cash Flows

	Three Months Ended March 31,
	2014												2013
	NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated			NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
NET CASH PROVIDED BY OPERATING ACTIVITIES	$	428		$	147		$	442		$	1,017		$	350		$	295		$	437		$	1,082
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	—			(798		)	(1,068		)	(1,866		)	—			(1,046		)	(821		)	(1,867		)
Capital contribution to FPL	(100		)	—			100			—			—			—			—			—
Cash grants under the Recovery Act	—			—			—			—			—			170			—			170
Change in loan proceeds restricted for construction	—			(28		)	—			(28		)	—			112			—			112
Other - net	—			58			(6		)	52			(52		)	29			30			7
Net cash used in investing activities	(100		)	(768		)	(974		)	(1,842		)	(52		)	(735		)	(791		)	(1,578		)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	—			655			—			655			—			623			—			623
Retirements of long-term debt	—			(688		)	(29		)	(717		)	—			(496		)	(427		)	(923		)
Net change in short-term debt	—			1,059			120			1,179			—			166			800			966
Dividends on common stock	(315		)	—			—			(315		)	(279		)	—			—			(279		)
Other - net	(8		)	(378		)	459			73			(21		)	39			(23		)	(5		)
Net cash provided by (used in) financing activities	(323		)	648			550			875			(300		)	332			350			382
Net increase (decrease) in cash and cash equivalents	5			27			18			50			(2		)	(108		)	(4		)	(114		)
Cash and cash equivalents at beginning of period	—			418			20			438			2			287			40			329
Cash and cash equivalents at end of period	$	5		$	445		$	38		$	488		$	—		$	179		$	36		$	215

————————————

(a) Represents FPL and consolidating adjustments.

XML

Common Shareholders' Equity (Earnings Per Share) (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013
Reconciliation of basic and diluted earnings per share of common stock [Abstract]
Income (loss) from continuing operations	$ 430		$ 41	[1],[2]
Denominator:
Weighted-average number of common shares outstanding - basic (in shares)	433.5		421.0
Performance share awards, options, equity units and restricted stock (in shares)	4.7	[3]	2.7	[3]
Weighted-average number of common shares outstanding - assuming dilution (in shares)	438.2		423.7
Earnings per share of common stock from continuing operations:
Basic	$ 0.99		$ 0.10
Assuming dilution	$ 0.98		$ 0.10
Antidilutive securities (in shares)	0.1		0.4

[1] (c)Prior year amounts were restated to conform to current year's presentation. See Note 3 - Nonrecurring Fair Value Measurements.

[2] Certain amounts were restated to conform to current year's presentation. See Note 3 - Nonrecurring Fair Value Measurements

[3] 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.

XML

Derivative Instruments (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]
Maximum length of time hedged in interest rate cash flow hedges	through June 2031
Maximum Length of Time Hedged in Foreign Currency Cash Flow Hedge	16 years 6 months
Margin cash collateral received from counterparties that was not offset against derivative assets	$ 45	$ 24
Margin cash collateral provided to counterparties that was not offset against derivative liabilities	109	42
Total gain (loss) to be reclassified during next 12 months	$ (61)

XML

Derivative Instruments (Balance Sheet Disclosure) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2014		Dec. 31, 2013
Derivatives, Fair Value [Line Items]
Derivative Asset	$ 1,517		$ 1,661
Derivative Liability	1,211		1,311
Current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Amount Offset Against Collateral	165		181
Derivative Asset	533	[1]	498	[2]
Current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability	815		838
Non Current Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Amount Offset Against Collateral	88		98
Derivative Asset	984	[3]	1,163	[4]
Noncurrent derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Amount Offset Against Collateral	12
Derivative Liability	396	[5]	473
Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset	1,441		1,571
Derivative Liability	834		940
Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset	76		90
Derivative Liability	233		220
Foreign Exchange Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset	0		0
Derivative Liability	144		151
FPL [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset	130		48
Derivative Liability	10		2
FPL [Member] | Current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset	129		48
FPL [Member] | Current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability			1
FPL [Member] | Non Current Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset	1
FPL [Member] | Noncurrent derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability	10		1
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	4,553		4,544
Derivative Liability, Fair Value, Gross Liability	3,908		3,827
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	76		89
Derivative Liability, Fair Value, Gross Liability	174		177
Foreign Exchange Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Derivative Liability, Fair Value, Gross Liability	95		101
Foreign Exchange Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Derivative Liability, Fair Value, Gross Liability	49		50
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		1
Derivative Liability, Fair Value, Gross Liability	108		93
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	76		89
Derivative Liability, Fair Value, Gross Liability	125		127
Commodity Contract [Member] | FPL [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset	130		48
Derivative Liability	10		2
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	4,553		4,543
Derivative Liability, Fair Value, Gross Liability	3,705		3,633
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | FPL [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	123		55
Derivative Liability, Fair Value, Gross Liability	3		9
Commodity Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Derivative Liability, Fair Value, Gross Liability	0		0
Commodity Contract [Member] | Designated as Hedging Instrument [Member] | FPL [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Derivative Liability, Fair Value, Gross Liability	$ 0		$ 0

[1] Reflects the netting of approximately $165 million in margin cash collateral received from counterparties.

[2] Reflects the netting of approximately $181 million in margin cash collateral received from counterpar

[3] Reflects the netting of approximately $88 million in margin cash collateral received from counterparties.

[4] Reflects the netting of approximately $98 million in margin cash collateral received from counterpar

[5] Reflects the netting of approximately $12 million in margin cash collateral provided to counterparties.

XML

Employee Retirement Benefits

3 Months Ended

Mar. 31, 2014

Compensation and Retirement Disclosure [Abstract]

Employee Retirement Benefits

Employee Retirement Benefits

NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries and has a supplemental executive retirement plan, which includes a non-qualified supplemental defined benefit pension component that provides benefits to a select group of management and highly compensated employees (collectively, pension benefits).  In addition to pension benefits, NEE sponsors a contributory postretirement plan for health care and life insurance benefits (other benefits) for retirees of NEE and its subsidiaries meeting certain eligibility requirements.

The components of net periodic benefit (income) cost for the plans are as follows:

	Pension Benefits						Other Benefits
	Three Months Ended   March 31,						Three Months Ended   March 31,
	2014			2013			2014			2013
	(millions)
Service cost	$	16		$	18		$	1		$	1
Interest cost	25			24			4			4
Expected return on plan assets	(60		)	(60		)	—			—
Amortization of prior service cost (benefit)	1			2			(1		)	(1		)
Amortization of losses	—			1			—			1
Net periodic benefit (income) cost at NEE	$	(18	)	$	(15	)	$	4		$	5
Net periodic benefit (income) cost at FPL	$	(11	)	$	(10	)	$	3		$	3

XML

Derivative Instruments (Income Statement Disclosure) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013
Effect of Cash Flow Hedges on Results of Operations [Abstract]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	$ (29)		$ 92
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	(14)		(34)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(298)		(71)
Gains (losses) on commodity contracts, recorded as regulatory assets and or liabilities on the balance sheet due to regulatory treatment	136		144
Commodity Contract [Member] | Gains (losses) included in operating revenues [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(272)		(42)
Commodity Contract [Member] | Gains (losses) included in fuel, purchased power and interchange [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(4)		3
Interest Rate Contract [Member]
Effect of Cash Flow Hedges on Results of Operations [Abstract]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	(27)		100
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	(16)	[1]	(15)	[1]
Interest Rate Contract [Member] | Gain Loss Included In Interest Expense Member
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(27)		0
Foreign Exchange Contract [Member]
Effect of Cash Flow Hedges on Results of Operations [Abstract]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	(2)		(8)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	2	[2]	(19)	[2]
Foreign Exchange Contract [Member] | Gains (losses) included in Other - net [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	5		(32)
Fair Value Hedging [Member]
Derivative [Line Items]
Increase (Decrease) in Fair Value of Hedged Item in Interest Rate Fair Value Hedge	4		(9)
Cash Flow Hedging [Member] | Currency Swap [Member] | Gains (losses) included in interest expense [Member]
Derivative [Line Items]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	$ (1)		$ (1)

[1] Included in interest expense.

[2] Loss of approximately $1 million is included in interest expense and the balance is included in other - net.

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Fair Value Measurements (Available for Sale Securities) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014 FPL [Member]	Mar. 31, 2013 FPL [Member]	Mar. 31, 2014 Available For Sale Securities: Special Use Funds - Equity Securities [Member]	Dec. 31, 2013 Available For Sale Securities: Special Use Funds - Equity Securities [Member]	Mar. 31, 2014 Available For Sale Securities: Special Use Funds - Equity Securities [Member] FPL [Member]	Dec. 31, 2013 Available For Sale Securities: Special Use Funds - Equity Securities [Member] FPL [Member]	Mar. 31, 2014 available for sale securities: Special Use Funds - Debt Securities [Member]		Dec. 31, 2013 available for sale securities: Special Use Funds - Debt Securities [Member]		Mar. 31, 2014 available for sale securities: Special Use Funds - Debt Securities [Member] FPL [Member]		Dec. 31, 2013 available for sale securities: Special Use Funds - Debt Securities [Member] FPL [Member]
Schedule of Available-for-sale Securities [Line Items]
Unrealized Loss									$ 12	[1]	$ 32	[1]	$ 10	[1]	$ 25	[1]
Unrealized gains					1,105	1,125	780	777	49		42		41		36
Realized Gains	77	42	32	23
Realized Losses	22	30	17	22
Proceeds from Sale and Maturity of Available-for-sale Securities	1,401	924	1,162	685
Available-for-sale Securities, Continuous Unrealized Loss Position, Fair Value									$ 660		$ 1,069		$ 516		$ 844

[1] Unrealized losses on available for sale debt securities for securities in an unrealized loss position for greater than twelve months at March 31, 2014 and December 31, 2013 were not material to NEE or FPL.

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CONDENSED CONSOLIDATED STATEMENTS OF INCOME (unaudited) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013
OPERATING REVENUES	$ 3,674		$ 3,279
OPERATING EXPENSES
Fuel, purchased power and interchange	1,397		1,065
Other operations and maintenance	756		756
Impairment charge	0		300
Depreciation and amortization	463		419
Taxes other than income taxes and other	320		305
Total operating expenses	2,936		2,845
OPERATING INCOME	738		434
OTHER INCOME (DEDUCTIONS)
Interest expense	(319)		(272)
Benefits associated with differential membership interests - net	65		40
Allowance for equity funds used during construction	15		26
Interest income	22		19
Gains on disposal of assets - net	44		12
Gain (loss) associated with Maine fossil	21		(67)
Other - net	(3)		(7)
Total other deductions - net	(155)		(249)
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	583		185	[1]
INCOME TAXES	153		144	[1]
INCOME FROM CONTINUING OPERATIONS	430		41	[1],[2]
GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	0		231	[1],[2],[3]
NET INCOME	430		272
Earnings per share of common stock:
Continuing operations	$ 0.99		$ 0.10
Discontinued operations	$ 0.00		$ 0.55
Net income	$ 0.99		$ 0.65
Continuing operations, assuming dilution	$ 0.98		$ 0.10
Discontinued operations, assuming dilution	$ 0.00		$ 0.54
Net Income	$ 0.98		$ 0.64
Dividends per share of common stock	$ 0.725		$ 0.66
Weighted-average number of common shares outstanding:
Basic	433.5		421.0
Assuming dilution	438.2		423.7
FPL [Member]
OPERATING REVENUES	2,535		2,188
OPERATING EXPENSES
Fuel, purchased power and interchange	1,036		820
Other operations and maintenance	384		385
Depreciation and amortization	209		181
Taxes other than income taxes and other	274		259
Total operating expenses	1,903		1,645
OPERATING INCOME	632		543
OTHER INCOME (DEDUCTIONS)
Interest expense	(102)		(102)
Allowance for equity funds used during construction	15		18
Other - net	1		1
Total other deductions - net	(86)		(83)
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	546		460
INCOME TAXES	199		172
GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	0		0
NET INCOME	$ 347	[4]	$ 288	[4]

[1] Certain amounts were restated to conform to current year's presentation. See Note 3 - Nonrecurring Fair Value Measurements

[2] (c)Prior year amounts were restated to conform to current year's presentation. See Note 3 - Nonrecurring Fair Value Measurements.

[3] See Note 5.

[4] (a)FPL's comprehensive income is the same as reported net income.

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Common Shareholders' Equity (Accumulated Other Comprehensive Income) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013
Components Of Comprehensive Income And Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance	$ 56		$ (255)
Other comprehensive income (loss) before reclassifications	(20)		103
Amounts reclassified from AOCI	(15)		16
Net other comprehensive income (loss)	(35)		119
Ending balance	21		(136)
Net Unrealized Gains (Losses) on Available for Sale Securities
Components Of Comprehensive Income And Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance	197		96
Other comprehensive income (loss) before reclassifications	13		40
Amounts reclassified from AOCI	(25)	[1]	(6)	[1]
Net other comprehensive income (loss)	(12)		34
Ending balance	185		130
Net Unrealized Gains (Losses) on Cash Flow Hedges
Components Of Comprehensive Income And Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance	(115)		(266)
Other comprehensive income (loss) before reclassifications	(18)		65
Amounts reclassified from AOCI	9	[2]	21	[2]
Net other comprehensive income (loss)	(9)		86
Ending balance	(124)		(180)
Defined Benefit Pension and Other Benefits Plans
Components Of Comprehensive Income And Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance	23		(74)
Other comprehensive income (loss) before reclassifications	4		6
Amounts reclassified from AOCI	1		1
Net other comprehensive income (loss)	5		7
Ending balance	28		(67)
Net Unrealized Gains (Losses) on Foreign Currency Translation
Components Of Comprehensive Income And Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance	(33)		12
Other comprehensive income (loss) before reclassifications	(17)		(9)
Amounts reclassified from AOCI	0		0
Net other comprehensive income (loss)	(17)		(9)
Ending balance	(50)		3
Other Comprehensive Income (Loss) Related to Equity Method Investee
Components Of Comprehensive Income And Accumulated Other Comprehensive Income Loss [Line Items]
Beginning balance	(16)		(23)
Other comprehensive income (loss) before reclassifications	(2)		1
Amounts reclassified from AOCI	0		0
Net other comprehensive income (loss)	(2)		1
Ending balance	$ (18)		$ (22)

[1] Reclassified to gains on disposal of assets - net in NEE's condensed consolidated statements of income.

[2] Reclassified to interest expense and other - net in NEE's condensed consolidated statements of income. See Note 2 - Income Statement Impact of Derivative Instruments.

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CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) (Parenthetical) (USD $) In Millions, except Share data, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
PROPERTY, PLANT AND EQUIPMENT
Total property, plant and equipment - net	$ 53,306	$ 52,720
CURRENT ASSETS
Customer receivables, allowances	18	14
OTHER ASSETS
Securitized storm-recovery costs	358	372
CAPITALIZATION
Long-term debt	23,824	23,969
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Common Stock, Shares Authorized	800,000,000	800,000,000
Common Stock, Shares, Outstanding	436,000,000	435,000,000
Related to VIEs [Member]
PROPERTY, PLANT AND EQUIPMENT
Total property, plant and equipment - net	5,077	5,127
OTHER ASSETS
Securitized storm-recovery costs	220	228
CAPITALIZATION
Long-term debt	1,190	1,207
FPL [Member]
CURRENT ASSETS
Customer receivables, allowances	4	5
OTHER ASSETS
Securitized storm-recovery costs	358	372
CAPITALIZATION
Long-term debt	8,443	8,473
Common Stock, No Par Value	$ 0	$ 0
Common Stock, Shares Authorized	1,000	1,000
Common Stock, Shares, Outstanding	1,000	1,000
Common Stock, Shares, Issued	1,000	1,000
FPL [Member] | Related to VIEs [Member]
OTHER ASSETS
Securitized storm-recovery costs	220	228
CAPITALIZATION
Long-term debt	$ 300	$ 331

XML

Fair Value Measurements (Assets and Liabilities Measured on a Recurring Basis) (Details) (Fair value measurements made on a recurring basis [Member], USD $) In Millions, unless otherwise specified	Mar. 31, 2014		Dec. 31, 2013
Cash equivalents:
Equity securities	$ 84		$ 20
Special use funds:
Equity securities	2,525	[1]	2,506	[1]
U.S. Government and municipal bonds	783	[1]	827	[1]
Corporate debt securities	612	[1]	597	[1]
Mortgage-backed securities	514	[1]	479	[1]
Other debt securities	69	[1]	60	[1]
Fair value of investments in commingled funds whose underlying investments would be Level 1 if those investments were held directly by the registrant			1,300
Other investments:
Equity Securities	44		51
Debt securities	124		118
Derivatives:
Commodity contracts	1,441	[2]	1,571	[2]
Interest rate contracts	76	[2]	90	[2]
Derivatives:
Commodity contracts	834	[2]	940	[2]
Interest rate swaps	233	[2]	220	[2]
Foreign currency swaps	144	[2]	151	[2]
Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member]
Cash equivalents:
Equity securities	84		20
Special use funds:
Equity securities	1,235	[1]	1,170	[1]
U.S. Government and municipal bonds	617	[1]	647	[1]
Corporate debt securities	0	[1]	0	[1]
Mortgage-backed securities	0	[1]	0	[1]
Other debt securities	25	[1]	16	[1]
Other investments:
Equity Securities	44		51
Debt securities	21		11
Derivatives:
Commodity contracts	1,529		1,368
Interest rate contracts	0		0
Derivatives:
Commodity contracts	1,434		1,285
Interest rate swaps	0		0
Foreign currency swaps	0		0
Significant Other Observable Inputs (Level 2) [Member]
Cash equivalents:
Equity securities	0		0
Special use funds:
Equity securities	1,290	[1],[3]	1,336	[1],[4]
U.S. Government and municipal bonds	166	[1]	180	[1]
Corporate debt securities	612	[1]	597	[1]
Mortgage-backed securities	514	[1]	479	[1]
Other debt securities	44	[1]	44	[1]
Other investments:
Equity Securities	0		0
Debt securities	103		107
Derivatives:
Commodity contracts	1,989		2,106
Interest rate contracts	76		90
Derivatives:
Commodity contracts	1,804		1,994
Interest rate swaps	125		127
Foreign currency swaps	144		151
Significant Unobservable Inputs (Level 3) [Member]
Cash equivalents:
Equity securities	0		0
Special use funds:
Equity securities	0	[1]	0	[1]
U.S. Government and municipal bonds	0	[1]	0	[1]
Corporate debt securities	0	[1]	0	[1]
Mortgage-backed securities	0	[1]	0	[1]
Other debt securities	0	[1]	0	[1]
Other investments:
Equity Securities	0		0
Debt securities	0		0
Derivatives:
Commodity contracts	1,035		1,069
Interest rate contracts	0		0
Derivatives:
Commodity contracts	467		354
Interest rate swaps	108		93
Foreign currency swaps	0		0
Netting [Member]
Cash equivalents:
Equity securities	0	[5]	0	[5]
Special use funds:
Equity securities	0	[1],[5]	0	[1],[5]
U.S. Government and municipal bonds	0	[1],[5]	0	[1],[5]
Corporate debt securities	0	[1],[5]	0	[1],[5]
Mortgage-backed securities	0	[1],[5]	0	[1],[5]
Other debt securities	0	[1],[5]	0	[1],[5]
Other investments:
Equity Securities	0	[5]	0	[5]
Debt securities	0	[5]	0	[5]
Derivatives:
Commodity contracts	(3,112)	[5]	(2,972)	[5]
Interest rate contracts	0	[5]	0	[5]
Derivatives:
Commodity contracts	(2,871)	[5]	(2,693)	[5]
Interest rate swaps	0	[5]	0	[5]
Foreign currency swaps	0	[5]	0	[5]
FPL [Member]
Special use funds:
Equity securities	1,494	[1]	1,467	[1]
U.S. Government and municipal bonds	667	[1]	738	[1]
Corporate debt securities	427	[1]	421	[1]
Mortgage-backed securities	438	[1]	401	[1]
Other debt securities	50	[1]	46	[1]
Fair value of investments in commingled funds whose underlying investments would be Level 1 if those investments were held directly by the registrant			1,141
Derivatives:
Commodity contracts	130	[2]	48	[2]
Derivatives:
Commodity contracts	10	[2]	2	[2]
FPL [Member] | Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member]
Special use funds:
Equity securities	366	[1]	291	[1]
U.S. Government and municipal bonds	520	[1]	584	[1]
Corporate debt securities	0	[1]	0	[1]
Mortgage-backed securities	0	[1]	0	[1]
Other debt securities	25	[1]	16	[1]
Derivatives:
Commodity contracts	0		0
Derivatives:
Commodity contracts	0		0
FPL [Member] | Significant Other Observable Inputs (Level 2) [Member]
Special use funds:
Equity securities	1,128	[1],[3]	1,176	[1],[4]
U.S. Government and municipal bonds	147	[1]	154	[1]
Corporate debt securities	427	[1]	421	[1]
Mortgage-backed securities	438	[1]	401	[1]
Other debt securities	25	[1]	30	[1]
Derivatives:
Commodity contracts	119		53
Derivatives:
Commodity contracts	2		7
FPL [Member] | Significant Unobservable Inputs (Level 3) [Member]
Special use funds:
Equity securities	0	[1]	0	[1]
U.S. Government and municipal bonds	0	[1]	0	[1]
Corporate debt securities	0	[1]	0	[1]
Mortgage-backed securities	0	[1]	0	[1]
Other debt securities	0	[1]	0	[1]
Derivatives:
Commodity contracts	4		2
Derivatives:
Commodity contracts	1		2
FPL [Member] | Netting [Member]
Special use funds:
Equity securities	0	[1],[5]	0	[1],[5]
U.S. Government and municipal bonds	0	[1],[5]	0	[1],[5]
Corporate debt securities	0	[1],[5]	0	[1],[5]
Mortgage-backed securities	0	[1],[5]	0	[1],[5]
Other debt securities	0	[1],[5]	0	[1],[5]
Derivatives:
Commodity contracts	7	[5]	(7)	[5]
Derivatives:
Commodity contracts	$ 7	[5]	$ (7)	[5]

[1] 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 the Carrying Amount below.

[2] See Note 2 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's condensed consolidated balance sheets.

[3] Invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

[4] At NEE, approximately $1,300 million ($1,141 million at FPL) are invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

[5] Includes the effect of the contractual ability to settle contracts under master netting arrangements and 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 condensed consolidated balance sheets and are recorded in customer receivables - net and accounts payable, respectively.

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Derivative Instruments (Tables)

3 Months Ended

Mar. 31, 2014

Derivative [Line Items]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]

	March 31, 2014
	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	$	—	$	—	$	4,553	$	3,705	$	1,441	$	834
Interest rate contracts	76		125		—		108		76		233
Foreign currency swaps	—		49		—		95		—		144
Total fair values	$	76	$	174	$	4,553	$	3,908	$	1,517	$	1,211
FPL:
Commodity contracts	$	—	$	—	$	123	$	3	$	130	$	10
Net fair value by NEE balance sheet line item:
Current derivative assets(a)									$	533
Noncurrent derivative assets(b)									984
Current derivative liabilities											$	815
Noncurrent derivative liabilities(c)											396
Total derivatives									$	1,517	$	1,211
Net fair value by FPL balance sheet line item:
Current other assets									$	129
Noncurrent other assets									1
Noncurrent other liabilities											$	10
Total derivatives									$	130	$	10

______________________

(a) Reflects the netting of approximately $165 million in margin cash collateral received from counterparties.

(b) Reflects the netting of approximately $88 million in margin cash collateral received from counterparties.

(c) Reflects the netting of approximately $12 million in margin cash collateral provided to counterparties.

	December 31, 2013
	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	$	—	$	—	$	4,543	$	3,633	$	1,571	$	940
Interest rate contracts	89		127		1		93		90		220
Foreign currency swaps	—		50		—		101		—		151
Total fair values	$	89	$	177	$	4,544	$	3,827	$	1,661	$	1,311
FPL:
Commodity contracts	$	—	$	—	$	55	$	9	$	48	$	2
Net fair value by NEE balance sheet line item:
Current derivative assets(a)									$	498
Noncurrent derivative assets(b)									1,163
Current derivative liabilities											$	838
Noncurrent derivative liabilities											473
Total derivatives									$	1,661	$	1,311
Net fair value by FPL balance sheet line item:
Current other assets									$	48
Current other liabilities											$	1
Noncurrent other liabilities											1
Total derivatives									$	48	$	2

______________________

(a) Reflects the netting of approximately $181 million in margin cash collateral received from counterparties.

(b) Reflects the netting of approximately $98 million in margin cash collateral received from counterparties.

Net notional volumes

NEE and FPL had derivative commodity contracts for the following net notional volumes:

	March 31, 2014					December 31, 2013
Commodity Type	NEE			FPL		NEE			FPL
	(millions)
Power	(111	)	MWh(a)	—		(276	)	MWh(a)	—
Natural gas	1,333		MMBtu(b)	937	MMBtu(b)	1,140		MMBtu(b)	674	MMBtu(b)
Oil	(9	)	barrels	—		(10	)	barrels	—

————————————

(a) Megawatt-hours

(b) One million British thermal units

Cash Flow Hedging [Member]

Derivative [Line Items]

Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Table Text Block]

Gains (losses) related to NEE's cash flow hedges are recorded in NEE's condensed consolidated financial statements (none at FPL) as follows:

	Three Months Ended March 31,
	2014											2013
	Interest Rate Contracts				Foreign Currency Swaps				Total			Interest Rate Contracts				Foreign Currency Swaps				Total
	(millions)
Gains (losses) recognized in OCI	$	(27	)		$	(2	)		$	(29	)	$	100			$	(8	)		$	92
Gains (losses) reclassified from AOCI to net income	$	(16	)	(a)	$	2		(b)	$	(14	)	$	(15	)	(a)	$	(19	)	(b)	$	(34	)

————————————

(a) Included in interest expense.

(b) Loss of approximately $1 million is included in interest expense and the balance is included in other - net.

Not Designated as Hedging Instrument [Member]

Derivative [Line Items]

Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Table Text Block]

Gains (losses) related to NEE's derivatives not designated as hedging instruments are recorded in NEE's condensed consolidated statements of income as follows:

	Three Months Ended   March 31,
	2014			2013
	(millions)
Commodity contracts:(a)
Operating revenues	$	(272	)	$	(42	)
Fuel, purchased power and interchange	(4		)	3
Foreign currency swap - other - net	5			(32		)
Interest rate contracts - interest expense	(27		)	—
Total	$	(298	)	$	(71	)

————————————

(a) For the three months ended March 31, 2014 and 2013, FPL recorded approximately $136 million and $144 million of gains, respectively, related to commodity contracts as regulatory liabilities on its condensed consolidated balance sheets.  

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Fair Value Measurements (Significant Unobservable Inputs Used in Valuation of Contracts) (Details) (Level 3 [Member], USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2014
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	$ 1,035
Liabilities, Fair Value Disclosure	467
Forward Contracts - power [Member] | Discounted Cash Flow Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	605
Liabilities, Fair Value Disclosure	106
Forward Contracts - power [Member] | Discounted Cash Flow Member] | Foward Price [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (in dollars per unit)	$ 9
Forward Contracts - power [Member] | Discounted Cash Flow Member] | Foward Price [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (in dollars per unit)	$ 156
Forward contracts - Gas [Member] | Discounted Cash Flow Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	96
Liabilities, Fair Value Disclosure	44
Forward contracts - Gas [Member] | Discounted Cash Flow Member] | Foward Price [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (in dollars per unit)	$ 2
Forward contracts - Gas [Member] | Discounted Cash Flow Member] | Foward Price [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (in dollars per unit)	$ 16
Forward contracts - other commodity related [Member] | Discounted Cash Flow Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	23
Liabilities, Fair Value Disclosure	16
Forward contracts - other commodity related [Member] | Discounted Cash Flow Member] | Foward Price [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (in dollars per unit)	$ 1
Forward contracts - other commodity related [Member] | Discounted Cash Flow Member] | Foward Price [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (in dollars per unit)	$ 245
Options - Power [Member] | Option Models [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	79
Liabilities, Fair Value Disclosure	84
Options - Power [Member] | Option Models [Member] | Implied Correlations [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	7.00%
Options - Power [Member] | Option Models [Member] | Implied Correlations [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	96.00%
Options - Power [Member] | Option Models [Member] | Implied Volatilities [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	1.00%
Options - Power [Member] | Option Models [Member] | Implied Volatilities [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	271.00%
Options - Gas [Member] | Option Models [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	34
Liabilities, Fair Value Disclosure	57
Options - Gas [Member] | Option Models [Member] | Implied Correlations [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	7.00%
Options - Gas [Member] | Option Models [Member] | Implied Correlations [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	96.00%
Options - Gas [Member] | Option Models [Member] | Implied Volatilities [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	1.00%
Options - Gas [Member] | Option Models [Member] | Implied Volatilities [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	70.00%
Full Requirements and Unit Contingent Contracts [Member] | Discounted Cash Flow Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets, Fair Value Disclosure	198
Liabilities, Fair Value Disclosure	160
Full Requirements and Unit Contingent Contracts [Member] | Discounted Cash Flow Member] | Foward Price [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (in dollars per unit)	$ (10)
Full Requirements and Unit Contingent Contracts [Member] | Discounted Cash Flow Member] | Foward Price [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (in dollars per unit)	$ 203
Full Requirements and Unit Contingent Contracts [Member] | Discounted Cash Flow Member] | Customer Migration Rate [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	0.00%	[1]
Full Requirements and Unit Contingent Contracts [Member] | Discounted Cash Flow Member] | Customer Migration Rate [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	20.00%	[1]
NextEra Energy Resources [Member] | Interest rate contracts [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Liabilities, Fair Value Disclosure	$ 108

[1] Applies only to full requirements contracts.

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Common Shareholders' Equity (Tables)

3 Months Ended

Mar. 31, 2014

Equity [Abstract]

Reconciliation of basic and diluted earnings per share of common stock

Earnings Per Share - The reconciliation of NEE's basic and diluted earnings per share of common stock from continuing operations is as follows:

	Three Months Ended   March 31,
	2014		2013
	(millions, except per share amounts)
Numerator - income from continuing operations	$	430	$	41
Denominator:
Weighted-average number of common shares outstanding - basic	433.5		421.0
Performance share awards, equity units, options, forward sale agreement and restricted stock(a)	4.7		2.7
Weighted-average number of common shares outstanding - assuming dilution	438.2		423.7
Earnings per share of common stock from continuing operations:
Basic	$	0.99	$	0.10
Assuming dilution	$	0.98	$	0.10

————————————

(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.

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 Gains (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	(18		)		13				4		(17		)	(2		)	(20		)
Amounts reclassified from AOCI	9			(a)	(25		)	(b)	1		—			—			(15		)
Net other comprehensive income (loss)	(9		)		(12		)		5		(17		)	(2		)	(35		)
Balances, March 31, 2014	$	(124	)		$	185			$	28	$	(50	)	$	(18	)	$	21

————————————

(a) Reclassified to interest expense and other - net in NEE's condensed consolidated statements of income.  See Note 2 - Income Statement Impact of Derivative Instruments.

(b) Reclassified to gains on disposal of assets - net in NEE's condensed consolidated statements of income.

	Accumulated Other Comprehensive Income (Loss)
	Net Unrealized Gains (Losses) on Cash Flow Hedges				Net Unrealized Gains (Losses) on Available for Sale Securities				Defined Benefit Pension and Other Benefits Plans			Net Unrealized Gains (Losses) on Foreign Currency Translation			Other Comprehensive Income (Loss) Related to Equity Method Investee			Total
	(millions)
Balances, December 31, 2012	$	(266	)		$	96			$	(74	)	$	12		$	(23	)	$	(255	)
Other comprehensive income (loss) before reclassifications	65				40				6			(9		)	1			103
Amounts reclassified from AOCI	21			(a)	(6		)	(b)	1			—			—			16
Net other comprehensive income (loss)	86				34				7			(9		)	1			119
Balances, March 31, 2013	$	(180	)		$	130			$	(67	)	$	3		$	(22	)	$	(136	)

————————————

(a) Reclassified to interest expense and other - net in NEE's condensed consolidated statements of income. See Note 2 - Income Statement Impact of Derivative Instruments.

(b) Reclassified to gains on disposal of assets - net in NEE's condensed consolidated statements of income.

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 430		$ 272
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	463		419
Nuclear fuel and other amortization	88		81
Impairment charge	0		300
Unrealized losses on marked to market energy contracts	124		42
Deferred income taxes	190		363
Benefits associated with differential membership interests - net	(65)		(40)
Allowance for equity funds used during construction	(15)		(26)
Gains on disposal of assets - net	(44)		(12)
Gain from discontinued operations, net of income taxes	0		(231)	[1],[2],[3]
Loss (gain) associated with Maine fossil	(21)		67
Other - net	47		67
Changes in operating assets and liabilities:
Customer and other receivables	(90)		136
Materials, supplies and fossil fuel inventory	9		(25)
Other current assets	(24)		(10)
Other assets	(97)		(25)
Accounts payable and customer deposits	162		42
Margin cash collateral	(84)		(2)
Income taxes	(42)		(205)
Interest and other taxes	122		74
Other current liabilities	(161)		(219)
Other liabilities	25		14
Net cash provided by operating activities	1,017		1,082
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL	(999)		(810)
Independent power and other investments of NEER	(752)		(972)
Cash grants under the American Recovery and Reinvestment Act of 2009	0		170
Nuclear fuel purchases	(91)		(24)
Other capital expenditures and other investments	(24)		(61)
Sale of independent power investments	53		0
Change in loan proceeds restricted for construction	(28)		112
Proceeds from sale or maturity of securities in special use funds	1,451		1,005
Purchases of securities in special use funds	(1,481)		(1,014)
Other - net	29		16
Net cash used in investing activities	(1,842)		(1,578)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	655		623
Retirements of long-term debt	(717)		(923)
Payments to differential membership investors	(22)		(20)
Net change in short-term debt	1,179		966
Issuances of common stock - net	25		8
Dividends	(315)		(279)
Other - net	70		7
Net cash provided by (used in) financing activities	875		382
Net increase (decrease) in cash and cash equivalents	50		(114)
Cash and cash equivalents at beginning of period	438		329
Cash and cash equivalents at end of period	488		215
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	802		674
Sale of hydropower generation plants through assumption of debt by buyer	0		700
Changes in property, plant and equipment as a result of a settlement	128		0
FPL [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	347	[4]	288	[4]
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	209		181
Nuclear fuel and other amortization	47		34
Deferred income taxes	168		238
Allowance for equity funds used during construction	(15)		(18)
Gain from discontinued operations, net of income taxes	0		0
Other - net	10		23
Changes in operating assets and liabilities:
Customer and other receivables	68		106
Materials, supplies and fossil fuel inventory	(22)		(2)
Other current assets	(18)		(17)
Other assets	(69)		(10)
Accounts payable and customer deposits	91		74
Income taxes	31		(66)
Interest and other taxes	95		81
Other current liabilities	(94)		(127)
Other liabilities	27		(9)
Net cash provided by operating activities	875		776
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL	(999)		(810)
Nuclear fuel purchases	(68)		(11)
Proceeds from sale or maturity of securities in special use funds	1,162		685
Purchases of securities in special use funds	(1,184)		(701)
Other - net	22		(1)
Net cash used in investing activities	(1,067)		(838)
CASH FLOWS FROM FINANCING ACTIVITIES
Retirements of long-term debt	(29)		(427)
Net change in short-term debt	120		800
Capital contribution from NEE	100		0
Dividends	0		(340)
Other - net	20		24
Net cash provided by (used in) financing activities	211		57
Net increase (decrease) in cash and cash equivalents	19		(5)
Cash and cash equivalents at beginning of period	19		40
Cash and cash equivalents at end of period	38		35
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	$ 317		$ 339

[1] See Note 5.

[2] (c)Prior year amounts were restated to conform to current year's presentation. See Note 3 - Nonrecurring Fair Value Measurements.

[3] Certain amounts were restated to conform to current year's presentation. See Note 3 - Nonrecurring Fair Value Measurements

[4] (a)FPL's comprehensive income is the same as reported net income.

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
NET INCOME	$ 430	$ 272
Net unrealized gains (losses) on cash flow hedges:
Effective portion of net unrealized gains (losses) (net of $11 tax benefit and $27 tax expense, respectively)	(18)	65
Reclassification from accumulated other comprehensive income to net income (net of $5 and $13 tax expense, respectively)	9	21
Net unrealized gains (losses) on available for sale securities:
Net unrealized gains on securities still held (net of $10 and $26 tax expense, respectively)	13	40
Reclassification from accumulated other comprehensive income to net income (net of $15 and $4 tax benefit, respectively)	(25)	(6)
Defined benefit pension and other benefits plans (net of $3 and $4 tax expense, respectively)	5	7
Net unrealized losses on foreign currency translation (net of $8 and $5 tax benefit, respectively)	(17)	(9)
Other comprehensive income (loss) related to equity method investee (net of $1 tax benefit in 2014)	(2)	1
Total other comprehensive income (loss), net of tax	(35)	119
COMPREHENSIVE INCOME	$ 395	$ 391

XML

Segment Information

3 Months Ended

Mar. 31, 2014

Segment Reporting [Abstract]

Segment Information

Segment Information

NEE's reportable segments are FPL, a rate-regulated electric utility, and NEER, a competitive energy business.  NEER's segment information includes an allocation of interest expense from NEECH based on a deemed capital structure of 70% debt and allocated shared service costs.  Corporate and Other represents other business activities, other segments that are not separately reportable and eliminating entries.  NEE's segment information is as follows:

	Three Months Ended March 31,
	2014										2013
	FPL		NEER(a)			Corporate and Other			NEE Consoli- dated		FPL		NEER(a)				Corporate and Other		NEE Consoli- dated
									(millions)
Operating revenues	$	2,535	$	1,034		$	105		$	3,674	$	2,188	$	1,016			$	75	$	3,279
Operating expenses	$	1,903	$	952		$	81		$	2,936	$	1,645	$	1,149		(b)	$	51	$	2,845
Income (loss) from continuing operations(c)	$	347	$	86	(d)	$	(3	)	$	430	$	288	$	(256	)	(d)	$	9	$	41
Gain from discontinued operations, net of income taxes(c)(e)	$	—	$	—		$	—		$	—	$	—	$	216			$	15	$	231
Net income (loss)	$	347	$	86	(d)	$	(3	)	$	430	$	288	$	(40	)	(d)	$	24	$	272

————————————

(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 non-utility interest expense is included in Corporate and Other.

(b) Includes an impairment charge on NEER's Spain solar projects of $300 million.  See Note 3 - Nonrecurring Fair Value Measurements.

(c) Prior year amounts were restated to conform to current year's presentation.  See Note 3 - Nonrecurring Fair Value Measurements.

(d) Includes NEER's tax benefits related to PTCs and in 2013 also includes after-tax charges of $342 million associated with the impairment of the Spain solar projects.  See Note 3 - Nonrecurring Fair Value Measurements and Note 4.

(e) See Note 5.

	March 31, 2014								December 31, 2013
	FPL		NEER		Corporate and Other		NEE Consoli- dated		FPL		NEER		Corporate and Other		NEE Consoli- dated
							(millions)
Total assets	$	37,189	$	30,335	$	2,807	$	70,331	$	36,488	$	30,154	$	2,664	$	69,306

XML

Document Entity Information Document	3 Months Ended
	Mar. 31, 2014
Entity Information [Line Items]
Entity Registrant Name	NEXTERA ENERGY INC
Entity Central Index Key	0000753308
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	436,118,602
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	Q1
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2014
FPL [Member]
Entity Information [Line Items]
Entity Registrant Name	FLORIDA POWER & LIGHT CO
Entity Central Index Key	0000037634
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding	1,000

XML

Summarized Financial Information of Capital Holdings

3 Months Ended

Mar. 31, 2014

Summarized Financial Information [Abstract]

Summarized Financial Information of Capital Holdings

11.  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.  Most of NEECH's debt, including its debentures, and payment guarantees are fully and unconditionally guaranteed by NEE.  Condensed consolidating financial information is as follows:

Condensed Consolidating Statements of Income

	Three Months Ended March 31,
	2014												2013(a)
	NEE (Guarantor)			NEECH			Other(b)			NEE Consoli- dated			NEE (Guarantor)			NEECH			Other(b)			NEE Consoli- dated
										(millions)
Operating revenues	$	—		$	1,142		$	2,532		$	3,674		$	—		$	1,094		$	2,185		$	3,279
Operating expenses	(4		)	(1,032		)	(1,900		)	(2,936		)	(3		)	(1,200		)	(1,642		)	(2,845		)
Interest expense	(2		)	(216		)	(101		)	(319		)	(2		)	(170		)	(100		)	(272		)
Equity in earnings of subsidiaries	435			—			(435		)	—			249			—			(249		)	—
Other income (deductions) - net	1			148			15			164			(2		)	5			20			23
Income (loss) from continuing operations before income taxes	430			42			111			583			242			(271		)	214			185
Income tax expense (benefit)	—			(46		)	199			153			(15		)	(16		)	175			144
Income (loss) from continuing operations	430			88			(88		)	430			257			(255		)	39			41
Gain from discontinued operations, net of income taxes	—			—			—			—			15			216			—			231
Net income (loss)	$	430		$	88		$	(88	)	$	430		$	272		$	(39	)	$	39		$	272

————————————

(a)  Certain amounts were restated to conform to current year's presentation.  See Note 3 - Nonrecurring Fair Value Measurements.

(b)  Represents FPL and consolidating adjustments.

Condensed Consolidating Statements of Comprehensive Income

	Three Months Ended March 31,
	2014									2013
	NEE (Guarantor)		NEECH		Other(a)			NEE Consoli- dated		NEE (Guarantor)		NEECH		Other(a)			NEE Consoli- dated
								(millions)
Comprehensive income (loss)	$	395	$	48	$	(48	)	$	395	$	391	$	73	$	(73	)	$	391

————————————

(a) Represents FPL and consolidating adjustments.

Condensed Consolidating Balance Sheets

	March 31, 2014												December 31, 2013
	NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated			NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	$	31		$	29,634		$	40,702		$	70,367		$	31		$	29,511		$	39,906		$	69,448
Less accumulated depreciation and amortization	(11		)	(5,965		)	(11,085		)	(17,061		)	(10		)	(5,774		)	(10,944		)	(16,728		)
Total property, plant and equipment - net	20			23,669			29,617			53,306			21			23,737			28,962			52,720
CURRENT ASSETS
Cash and cash equivalents	5			445			38			488			—			418			20			438
Receivables	121			2,107			323			2,551			78			1,542			669			2,289
Other	210			1,623			1,269			3,102			6			1,814			1,295			3,115
Total current assets	336			4,175			1,630			6,141			84			3,774			1,984			5,842
OTHER ASSETS
Investment in subsidiaries	17,962			—			(17,962		)	—			17,910			—			(17,910		)	—
Other	764			5,129			4,991			10,884			694			5,129			4,921			10,744
Total other assets	18,726			5,129			(12,971		)	10,884			18,604			5,129			(12,989		)	10,744
TOTAL ASSETS	$	19,082		$	32,973		$	18,276		$	70,331		$	18,709		$	32,640		$	17,957		$	69,306
CAPITALIZATION
Common shareholders' equity	$	18,160		$	4,432		$	(4,432	)	$	18,160		$	18,040		$	4,816		$	(4,816	)	$	18,040
Long-term debt	—			15,381			8,443			23,824			—			15,496			8,473			23,969
Total capitalization	18,160			19,813			4,011			41,984			18,040			20,312			3,657			42,009
CURRENT LIABILITIES
Debt due within one year	—			5,009			682			5,691			—			3,896			561			4,457
Accounts payable	—			758			692			1,450			—			589			611			1,200
Other	390			1,864			897			3,151			199			2,203			1,130			3,532
Total current liabilities	390			7,631			2,271			10,292			199			6,688			2,302			9,189
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	—			575			1,302			1,877			—			565			1,285			1,850
Deferred income taxes	251			1,982			6,073			8,306			166			1,963			6,015			8,144
Other	281			2,972			4,619			7,872			304			3,112			4,698			8,114
Total other liabilities and deferred credits	532			5,529			11,994			18,055			470			5,640			11,998			18,108
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	19,082		$	32,973		$	18,276		$	70,331		$	18,709		$	32,640		$	17,957		$	69,306

————————————

(a) Represents FPL and consolidating adjustments.

Condensed Consolidating Statements of Cash Flows

	Three Months Ended March 31,
	2014												2013
	NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated			NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
NET CASH PROVIDED BY OPERATING ACTIVITIES	$	428		$	147		$	442		$	1,017		$	350		$	295		$	437		$	1,082
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	—			(798		)	(1,068		)	(1,866		)	—			(1,046		)	(821		)	(1,867		)
Capital contribution to FPL	(100		)	—			100			—			—			—			—			—
Cash grants under the Recovery Act	—			—			—			—			—			170			—			170
Change in loan proceeds restricted for construction	—			(28		)	—			(28		)	—			112			—			112
Other - net	—			58			(6		)	52			(52		)	29			30			7
Net cash used in investing activities	(100		)	(768		)	(974		)	(1,842		)	(52		)	(735		)	(791		)	(1,578		)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	—			655			—			655			—			623			—			623
Retirements of long-term debt	—			(688		)	(29		)	(717		)	—			(496		)	(427		)	(923		)
Net change in short-term debt	—			1,059			120			1,179			—			166			800			966
Dividends on common stock	(315		)	—			—			(315		)	(279		)	—			—			(279		)
Other - net	(8		)	(378		)	459			73			(21		)	39			(23		)	(5		)
Net cash provided by (used in) financing activities	(323		)	648			550			875			(300		)	332			350			382
Net increase (decrease) in cash and cash equivalents	5			27			18			50			(2		)	(108		)	(4		)	(114		)
Cash and cash equivalents at beginning of period	—			418			20			438			2			287			40			329
Cash and cash equivalents at end of period	$	5		$	445		$	38		$	488		$	—		$	179		$	36		$	215

————————————

(a) Represents FPL and consolidating adjustments.

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) (Parenthetical) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Tax expense (benefit) of unrealized gains/losses on cash flow hedges	$ (11)	$ 27
Tax expense (benefit) on cash flow hedges reclassified from AOCI to net income	5	13
Tax expense (benefit) of unrealized gains/losses on available for sale securities still held	10	26
Tax expense (benefit) on available for sale securities reclassified from AOCI to net income	(15)	(4)
Tax expense (benefit) of defined benefit pension and other benefits plans	3	4
Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Tax	(8)	(5)
Other comprehensive income (loss) related to equity method investee, tax	$ (1)

XML

Discontinued Operations Discontinued Operations

3 Months Ended

Mar. 31, 2014

Discontinued Operations [Abstract]

Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]

Discontinued Operations

In March 2013, a subsidiary of NEER completed the sale of its ownership interest in a portfolio of hydropower generation plants and related assets (hydro sale) with a total generating capacity of 351 MW located in Maine and New Hampshire.  The sales price primarily included the assumption by the buyer of $700 million in related debt.In connection with the sale, a gain of approximately $372 million ($231 million after-tax) is reflected in gain from discontinued operations, net of income taxes in NEE's condensed consolidated statements of income for the three months ended March 31, 2013.  The operations of the hydropower generation plants, exclusive of the gain, were not material to NEE's condensed consolidated statements of income for the three months ended March 31, 2013.

See Note 3 - Nonrecurring Fair Value Measurements for a discussion of the decision not to pursue the sale of Maine fossil and the related financial statement impacts.

XML

Income Taxes

3 Months Ended

Mar. 31, 2014

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

NEE's effective income tax rates for the three months ended March 31, 2014 and 2013 were approximately 26% and 78%, respectively.  The rate for the three months ended March 31, 2013 reflects the establishment of a full valuation allowance of approximately $132 million on the deferred tax assets associated with the Spain solar projects.  This valuation allowance primarily related to deferred tax assets created as a result of the $300 million impairment and other related charges ($342 million after-tax) recorded for the three months ended March 31, 2013 (see Note 3 - Nonrecurring Fair Value Measurements).  In addition, the rates for both periods reflect the benefit of wind production tax credits (PTCs) of approximately $49 million and $59 million, respectively, related to NEER's wind projects and deferred income tax benefits associated with grants (convertible investment tax credits (ITCs)) under the American Recovery and Reinvestment Act of 2009, as amended (Recovery Act), of approximately $12 million and $13 million, respectively, primarily for certain wind and solar projects expected to be placed in service.

NEE recognizes PTCs as wind energy is generated and sold based on a per kilowatt-hour (kWh) rate prescribed in applicable federal and state statutes, which may differ significantly from amounts computed, on a quarterly basis, using an overall effective income tax rate anticipated for the full year.  NEE uses this method of recognizing PTCs for specific reasons, including that PTCs are an integral part of the financial viability of most wind projects and a fundamental component of such wind projects' results of operations.  PTCs, as well as deferred income tax benefits associated with convertible ITCs, can significantly affect NEE's effective income tax rate depending on the amount of pretax income.  The amount of PTCs recognized can be significantly affected by wind generation and by the roll off of PTCs after ten years of production (PTC roll off).

XML

Fair Value Measurements Fair Value Measurement (Tables)

3 Months Ended

Mar. 31, 2014

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:

	March 31, 2014
	Level 1		Level 2			Level 3		Netting(a)			Total
	(millions)
Assets:
Cash equivalents:
NEE - equity securities	$	84	$	—		$	—	$	—		$	84
Special use funds:(b)
NEE:
Equity securities	$	1,235	$	1,290	(c)	$	—	$	—		$	2,525
U.S. Government and municipal bonds	$	617	$	166		$	—	$	—		$	783
Corporate debt securities	$	—	$	612		$	—	$	—		$	612
Mortgage-backed securities	$	—	$	514		$	—	$	—		$	514
Other debt securities	$	25	$	44		$	—	$	—		$	69
FPL:
Equity securities	$	366	$	1,128	(c)	$	—	$	—		$	1,494
U.S. Government and municipal bonds	$	520	$	147		$	—	$	—		$	667
Corporate debt securities	$	—	$	427		$	—	$	—		$	427
Mortgage-backed securities	$	—	$	438		$	—	$	—		$	438
Other debt securities	$	25	$	25		$	—	$	—		$	50
Other investments:
NEE:
Equity securities	$	44	$	—		$	—	$	—		$	44
Debt securities	$	21	$	103		$	—	$	—		$	124
Derivatives:
NEE:
Commodity contracts	$	1,529	$	1,989		$	1,035	$	(3,112	)	$	1,441	(d)
Interest rate contracts	$	—	$	76		$	—	$	—		$	76	(d)
FPL - commodity contracts	$	—	$	119		$	4	$	7		$	130	(d)
Liabilities:
Derivatives:
NEE:
Commodity contracts	$	1,434	$	1,804		$	467	$	(2,871	)	$	834	(d)
Interest rate contracts	$	—	$	125		$	108	$	—		$	233	(d)
Foreign currency swaps	$	—	$	144		$	—	$	—		$	144	(d)
FPL - commodity contracts	$	—	$	2		$	1	$	7		$	10	(d)

————————————

(a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and 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 condensed consolidated balance sheets and are recorded in customer receivables - net and accounts payable, respectively.

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

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

(d) See Note 2 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's condensed consolidated balance sheets.

	December 31, 2013
	Level 1		Level 2			Level 3		Netting(a)			Total
	(millions)
Assets:
Cash equivalents:
NEE - equity securities	$	20	$	—		$	—	$	—		$	20
Special use funds:(b)
NEE:
Equity securities	$	1,170	$	1,336	(c)	$	—	$	—		$	2,506
U.S. Government and municipal bonds	$	647	$	180		$	—	$	—		$	827
Corporate debt securities	$	—	$	597		$	—	$	—		$	597
Mortgage-backed securities	$	—	$	479		$	—	$	—		$	479
Other debt securities	$	16	$	44		$	—	$	—		$	60
FPL:
Equity securities	$	291	$	1,176	(c)	$	—	$	—		$	1,467
U.S. Government and municipal bonds	$	584	$	154		$	—	$	—		$	738
Corporate debt securities	$	—	$	421		$	—	$	—		$	421
Mortgage-backed securities	$	—	$	401		$	—	$	—		$	401
Other debt securities	$	16	$	30		$	—	$	—		$	46
Other investments:
NEE:
Equity securities	$	51	$	—		$	—	$	—		$	51
Debt securities	$	11	$	107		$	—	$	—		$	118
Derivatives:
NEE:
Commodity contracts	$	1,368	$	2,106		$	1,069	$	(2,972	)	$	1,571	(d)
Interest rate contracts	$	—	$	90		$	—	$	—		$	90	(d)
FPL - commodity contracts	$	—	$	53		$	2	$	(7	)	$	48	(d)
Liabilities:
Derivatives:
NEE:
Commodity contracts	$	1,285	$	1,994		$	354	$	(2,693	)	$	940	(d)
Interest rate contracts	$	—	$	127		$	93	$	—		$	220	(d)
Foreign currency swaps	$	—	$	151		$	—	$	—		$	151	(d)
FPL - commodity contracts	$	—	$	7		$	2	$	(7	)	$	2	(d)

————————————

(a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and 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 condensed consolidated balance sheets and are recorded in customer receivables - net and accounts payable, respectively.

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

(c) At NEE, approximately $1,300 million ($1,141 million at FPL) are invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

(d) See Note 2 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's condensed consolidated balance sheets.

Significant unobservable inputs used in valuation of contracts categorized as Level 3

The significant unobservable inputs used in the valuation of NEE's commodity contracts categorized as Level 3 of the fair value hierarchy at March 31, 2014 are as follows:

Transaction Type	Fair Value at March 31, 2014				Valuation Technique(s)	Significant Unobservable Inputs	Range
	Assets		Liabilities
	(millions)
Forward contracts - power	$	605	$	106	Discounted cash flow	Forward price (per MWh)	$9	—	$156
Forward contracts - gas	96		44		Discounted cash flow	Forward price (per MMBtu)	$2	—	$16
Forward contracts - other commodity related	23		16		Discounted cash flow	Forward price (various)	$1	—	$245
Options - power	79		84		Option models	Implied correlations	7%	—	96%
						Implied volatilities	1%	—	271%
Options - gas	34		57		Option models	Implied correlations	7%	—	96%
						Implied volatilities	1%	—	70%
Full requirements and unit contingent contracts	198		160		Discounted cash flow	Forward price (per MWh)	$(10)	—	$203
						Customer migration rate(a)	—%	—	20%
Total	$	1,035	$	467

——————————

(a) Applies only to full requirements contracts.

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:

	Three Months Ended March 31,
	2014						2013
	NEE			FPL			NEE			FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at December 31	$	622		$	—		$	566		$	2
Realized and unrealized gains (losses):
Included in earnings(a)	(423		)	—			(3		)	—
Included in regulatory assets and liabilities	4			4			1			1
Purchases	4			—			49			—
Settlements	266			(1		)	(33		)	(1		)
Issuances	(19		)	—			(64		)	—
Transfers in(b)	7			—			—			—
Transfers out(b)	(1		)	—			6			—
Fair value of net derivatives based on significant unobservable inputs at March 31	$	460		$	3		$	522		$	2
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)	$	(249	)	$	—		$	32		$	—

————————————

(a) For the three months ended March 31, 2014, realized and unrealized losses of approximately $405 million are reflected in the condensed consolidated statements of income in operating revenues, $15 million in interest expense and the balance is reflected in fuel, purchased power and interchange.  For the three months ended March 31, 2013, realized and unrealized losses are reflected in the condensed consolidated statements of income in fuel, purchased power and interchange.

(b) Transfers into Level 3 were a result of decreased observability of market data and transfers from Level 3 to Level 2 were a result of increased observability of market data.  NEE's and FPL's policy is to recognize all transfers at the beginning of the reporting period.

(c) For the three months ended March 31, 2014, unrealized losses of $234 million are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in interest expense.  For the three months ended March 31, 2013, unrealized gains of approximately $31 million are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

Fair Value, by Balance Sheet Grouping

Fair Value of Financial Instruments Recorded at the Carrying Amount - The carrying amounts of cash equivalents, short-term debt and commercial paper approximate their fair values.  The carrying amounts and estimated fair values of other financial instruments, excluding those recorded at fair value and disclosed above in Recurring Fair Value Measurements, are as follows:

	March 31, 2014					December 31, 2013
	Carrying Amount		Estimated Fair Value			Carrying Amount		Estimated Fair Value
	(millions)
NEE:
Special use funds(a)	$	363	$	363		$	311	$	311
Other investments - primarily notes receivable	$	528	$	667	(b)	$	531	$	627	(b)
Long-term debt, including current maturities	$	27,639	$	28,782	(c)	$	27,728	$	28,612	(c)
FPL:
Special use funds(a)	$	251	$	251		$	200	$	200
Long-term debt, including current maturities	$	8,801	$	9,384	(c)	$	8,829	$	9,451	(c)

————————————

(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 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.  As of March 31, 2014 and December 31, 2013, NEE had no notes receivable reported in non-accrual status.

(c) As of March 31, 2014 and December 31, 2013, for NEE, $18,135 million and $17,921 million, respectively, is estimated using quoted market prices for the same or similar issues (Level 2); the balance is estimated using a discounted cash flow valuation technique, considering the current credit spread of the debtor (Level 3).  For FPL, 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
	Three Months Ended   March 31,				Three Months Ended   March 31,
	2014		2013		2014		2013
	(millions)
Realized gains	$	77	$	42	$	32	$	23
Realized losses	$	22	$	30	$	17	$	22
Proceeds from sale or maturity of securities	$	1,401	$	924	$	1,162	$	685

The unrealized gains on available for sale securities are as follows:

	NEE				FPL
	March 31, 2014		December 31, 2013		March 31, 2014		December 31, 2013
	(millions)
Equity securities	$	1,105	$	1,125	$	780	$	777
Debt securities	$	49	$	42	$	41	$	36

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
	March 31, 2014		December 31, 2013		March 31, 2014		December 31, 2013
	(millions)
Unrealized losses(a)	$	12	$	32	$	10	$	25
Fair value	$	660	$	1,069	$	516	$	844

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(a) Unrealized losses on available for sale debt securities for securities in an unrealized loss position for greater than twelve months at March 31, 2014 and December 31, 2013 were not material to NEE or FPL.

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Derivative Instruments (Policies)

3 Months Ended

Mar. 31, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives, Policy [Policy Text Block]

NEE and FPL use derivative instruments (primarily swaps, options, futures and forwards) to manage the 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 with outstanding and forecasted debt issuances, 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 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 the commodity price risk associated with the fuel requirements of the assets, where applicable, as well as 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 the 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 condensed 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 other - net in NEE's condensed consolidated statements of income.  Settlement gains and losses are included within the line items in the condensed 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 condensed 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 condensed consolidated statements of cash flows.

While most of NEE's derivatives are entered into for the purpose of managing commodity price risk, optimizing the value of NEER's power generation and gas infrastructure assets, reducing the impact of volatility in interest rates on outstanding and forecasted debt issuances and managing foreign currency risk, hedge accounting is only applied where specific criteria are met and it is practicable to do so.  In order to apply hedge accounting, the transaction must be designated as a hedge and it must be highly effective in offsetting the hedged risk.  Additionally, for hedges of forecasted transactions, the forecasted transactions must be probable.  For interest rate and foreign currency derivative instruments, generally NEE assesses a hedging instrument's effectiveness by using nonstatistical methods including dollar value comparisons of the change in the fair value of the derivative to the change in the fair value or cash flows of the hedged item.  Hedge effectiveness is tested at the inception of the hedge and on at least a quarterly basis throughout its life.  The effective portion of the gain or loss on a derivative instrument designated as a cash flow hedge is reported as a component of other comprehensive income (OCI) and is reclassified into earnings in the period(s) during which the transaction being hedged affects earnings or when it becomes probable that a forecasted transaction being hedged would not occur.  The ineffective portion of net unrealized gains (losses) on these hedges is reported in earnings in the current period.

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Debt

3 Months Ended

Mar. 31, 2014

Debt Disclosure [Abstract]

Debt

Debt

Significant long-term debt issuances and borrowings by subsidiaries of NEE during the three months ended March 31, 2014 were as follows:

Date Issued	Company	Debt Issuances/Borrowings	Interest Rate			Principal Amount		Maturity Date
						(millions)
January - March 2014	NEER subsidiary	Canadian revolving credit agreements	Variable		(a)	$	245	Various
January 2014	NEER subsidiary	Senior secured limited-recourse term loan	Variable		(a)	$	44	2019
March 2014	NEECH	Debentures	2.700	%	(b)	$	350	2019

————————————

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

(b) An interest rate swap agreement has been entered into with respect to this issuance.  See Note 2.

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Variable Interest Entities (VIEs)

3 Months Ended

Mar. 31, 2014

Variable Interest Entities [Abstract]

Variable Interest Entities (VIEs)

Variable Interest Entities (VIEs)

As of March 31, 2014, NEE has fourteen 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 $290 million and $324 million at March 31, 2014 and December 31, 2013, respectively, and consisted primarily of storm-recovery property, which are included in securitized storm-recovery costs on NEE's and FPL's condensed consolidated balance sheets.  The liabilities of the VIE were approximately $360 million and $394 million at March 31, 2014 and December 31, 2013, respectively, and consisted primarily of storm-recovery bonds, which are included in long-term debt on NEE's and FPL's condensed consolidated balance sheets.

FPL identified a potential VIE, which is considered a qualifying facility as defined by the Public Utility Regulatory Policies Act of 1978, as amended (PURPA).  PURPA requires utilities, such as FPL, to purchase the electricity output of a qualifying facility.  FPL entered into a purchased power agreement effective in 1994 with this 250 MW coal-fired qualifying facility to purchase substantially all of the facility's capacity and electrical output over a substantial portion of its estimated useful life.  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).  After making exhaustive efforts, FPL was unable to obtain the information from the facility necessary to determine whether the facility is a VIE or whether FPL is the primary beneficiary of the facility.  The purchased power agreement with the facility contains no provision which legally obligates the facility to release this information to FPL.  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.  Notwithstanding the fact that FPL's energy payments are recovered through the fuel clause, if the facility was determined to be a VIE, the absorption of some of the facility's fuel price variability might cause FPL to be considered the primary beneficiary.  During the three months ended March 31, 2014 and 2013, FPL purchased 128,940 MWh and 79,210 MWh, respectively, from the facility at a total cost of approximately $36 million and $35 million, respectively.

Additionally, FPL entered into a purchased power agreement effective in 1995 with a 330 MW coal-fired qualifying facility to purchase substantially all of the facility's 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 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.

NEER - NEE consolidates thirteen 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, and through its 100% equity ownership has the obligation to absorb expected losses of these VIEs.

A NEER VIE consolidates two entities which own and operate natural gas/oil electric generating facilities with the capability of producing 110 MW.  This VIE sells its 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.  This VIE uses third-party debt and equity to finance its operations.  The debt is secured by liens against the generating 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 $90 million and $65 million, respectively, at March 31, 2014 and $85 million and $63 million, respectively, at December 31, 2013, and consisted primarily of property, plant and equipment and long-term debt.

The other twelve NEER VIEs consolidate several entities which own and operate wind electric generating facilities with the capability of producing a total of 3,541 MW.  Ten of these VIEs sell their electric output under power sales contracts to third parties with expiration dates ranging from 2018 through 2038; the other two VIEs sell their electric output in the spot market.  The VIEs use third-party debt and/or equity to finance their operations.  Certain investors that hold no equity interest in the VIEs hold differential membership interests, which give them the right to receive a portion of the economic attributes of the generating facilities, including certain tax attributes.  The debt is secured by liens against the generating 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 $5.2 billion and $3.3 billion, respectively, at March 31, 2014 and $5.3 billion and $3.3 billion, respectively, at December 31, 2013.  At March 31, 2014 and December 31, 2013, 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 March 31, 2014 and December 31, 2013, several NEE subsidiaries have investments totaling approximately $700 million ($541 million at FPL) and $668 million ($505 million at FPL), respectively, in certain special purpose entities, which consisted primarily of investments in mortgage-backed securities.  These investments are included in special use funds and other investments on NEE's condensed consolidated balance sheets and in special use funds on FPL's condensed consolidated balance sheets.  As of March 31, 2014, NEE subsidiaries 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

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Common Shareholders' Equity

3 Months Ended

Mar. 31, 2014

Equity [Abstract]

Common Shareholders' Equity

Common Shareholders' Equity

Earnings Per Share - The reconciliation of NEE's basic and diluted earnings per share of common stock from continuing operations is as follows:

	Three Months Ended   March 31,
	2014		2013
	(millions, except per share amounts)
Numerator - income from continuing operations	$	430	$	41
Denominator:
Weighted-average number of common shares outstanding - basic	433.5		421.0
Performance share awards, equity units, options, forward sale agreement and restricted stock(a)	4.7		2.7
Weighted-average number of common shares outstanding - assuming dilution	438.2		423.7
Earnings per share of common stock from continuing operations:
Basic	$	0.99	$	0.10
Assuming dilution	$	0.98	$	0.10

————————————

(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 stock options and performance shares awards and restricted stock which were not included in the denominator above due to their antidilutive effect were approximately 0.1 million and 0.4 million for the three months ended March 31, 2014 and 2013, respectively.

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

	Accumulated Other Comprehensive Income (Loss)
	Net Unrealized Gains (Losses) on Cash Flow Hedges				Net Unrealized Gains (Losses) on Available for Sale Securities				Defined Benefit Pension and Other Benefits Plans		Net Unrealized Gains (Losses) on Foreign Currency Translation			Other Comprehensive Income (Loss) Related to Equity Method Investee			Total
	(millions)
Balances, December 31, 2013	$	(115	)		$	197			$	23	$	(33	)	$	(16	)	$	56
Other comprehensive income (loss) before reclassifications	(18		)		13				4		(17		)	(2		)	(20		)
Amounts reclassified from AOCI	9			(a)	(25		)	(b)	1		—			—			(15		)
Net other comprehensive income (loss)	(9		)		(12		)		5		(17		)	(2		)	(35		)
Balances, March 31, 2014	$	(124	)		$	185			$	28	$	(50	)	$	(18	)	$	21

————————————

(a) Reclassified to interest expense and other - net in NEE's condensed consolidated statements of income.  See Note 2 - Income Statement Impact of Derivative Instruments.

(b) Reclassified to gains on disposal of assets - net in NEE's condensed consolidated statements of income.

	Accumulated Other Comprehensive Income (Loss)
	Net Unrealized Gains (Losses) on Cash Flow Hedges				Net Unrealized Gains (Losses) on Available for Sale Securities				Defined Benefit Pension and Other Benefits Plans			Net Unrealized Gains (Losses) on Foreign Currency Translation			Other Comprehensive Income (Loss) Related to Equity Method Investee			Total
	(millions)
Balances, December 31, 2012	$	(266	)		$	96			$	(74	)	$	12		$	(23	)	$	(255	)
Other comprehensive income (loss) before reclassifications	65				40				6			(9		)	1			103
Amounts reclassified from AOCI	21			(a)	(6		)	(b)	1			—			—			16
Net other comprehensive income (loss)	86				34				7			(9		)	1			119
Balances, March 31, 2013	$	(180	)		$	130			$	(67	)	$	3		$	(22	)	$	(136	)

————————————

(a) Reclassified to interest expense and other - net in NEE's condensed consolidated statements of income. See Note 2 - Income Statement Impact of Derivative Instruments.

(b) Reclassified to gains on disposal of assets - net in NEE's condensed consolidated statements of income.

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2014

Commitments and Contingencies [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.  Capital expenditures for Corporate and Other primarily include the cost for construction of a natural gas pipeline system for new natural gas transportation infrastructure in Florida, as well as the cost to meet customer-specific requirements and maintain the fiber-optic network for the fiber-optic telecommunications business (FPL FiberNet) and the cost to maintain existing transmission facilities at NextEra Energy Transmission, LLC (NEET).

At March 31, 2014, estimated capital expenditures for the remainder of 2014 through 2018 were as follows:

	Remainder of 2014		2015		2016		2017		2018		Total
	(millions)
FPL:
Generation:(a)
New(b)(c)	$	475	$	295	$	70	$	—	$	—	$	840
Existing	565		680		610		580		545		2,980
Transmission and distribution	1,055		1,200		1,125		955		1,025		5,360
Nuclear fuel	80		210		220		190		180		880
General and other	130		155		120		165		160		730
Total(d)	$	2,305	$	2,540	$	2,145	$	1,890	$	1,910	$	10,790
NEER:
Wind(e)	$	1,505	$	610	$	25	$	10	$	15	$	2,165
Solar(f)	480		750		520		—		—		1,750
Nuclear(g)	265		275		295		255		265		1,355
Other(h)	345		20		75		40		75		555
Total	$	2,595	$	1,655	$	915	$	305	$	355	$	5,825
Corporate and Other(i)	$	190	$	445	$	795	$	225	$	95	$	1,750

————————————

(a) Includes allowance for funds used during construction (AFUDC) of approximately $28 million, $53 million and $17 million for the remainder of 2014 through 2016, respectively.

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

(c) Consists of projects that have received FPSC approval. Excludes capital expenditures for the construction costs for the two additional nuclear units at FPL's Turkey Point site beyond what is required to receive an NRC license for each unit.

(d) FPL has identified $1.5 billion to $2.5 billion in potential incremental capital expenditures through 2016 in addition to what is included in the table above.

(e) Consists of capital expenditures for new wind projects and related transmission totaling approximately 1,815 MW, including approximately 465 MW in Canada, that have received applicable internal approvals.  NEER expects to add new U.S. wind generation of 2,000 MW to 2,500 MW in 2013 through 2015, including 325 MW added to date, at a total cost of up to $3.5 billion to $4.5 billion.

(f) Consists of capital expenditures for new solar projects and related transmission totaling approximately 600 MW that have received applicable internal approvals, including equity contributions associated with a 50% equity investment in a 550 MW solar project.  Includes approximately $1 billion of total estimated costs associated with the pending acquisition of the development rights for a 250 MW solar project that is expected to close in mid-2014, subject to certain conditions precedent, and construction of the project, which is expected to be completed in 2016.  Excludes solar projects requiring internal approvals with generation totaling 47 MW with an estimated cost of approximately $120 million.

(g) Includes nuclear fuel.

(h) Consists of capital expenditures that have received applicable internal approvals.

(i) Includes capital expenditures totaling approximately $1.4 billion for the remainder of 2014 through 2018 for construction of a natural gas pipeline system that has received applicable internal approvals, including approximately $885 million of equity contributions associated with a 33% equity investment in the northern portion of the natural gas pipeline system and $525 million for the southern portion, which includes AFUDC of approximately $1 million, $7 million, $20 million and $12 million for the remainder of 2014 through 2017, respectively.  The natural gas pipeline system is subject to certain conditions, including FERC approval.  A FERC decision is expected in 2015. 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 March 31, 2014, FPL is obligated under take-or-pay purchased power contracts with JEA and with subsidiaries of The Southern Company (Southern subsidiaries) to pay for approximately 1,330 MW annually through 2015 and 375 MW annually thereafter through 2021.  FPL also has various firm pay-for-performance contracts to purchase approximately 705 MW from certain cogenerators and small power producers (qualifying facilities) with expiration dates ranging from 2024 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 qualifying 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 NEECH subsidiary has a 33% ownership interest), and Florida Southeast Connection, LLC (Florida Southeast Connection, a wholly-owned NEECH 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 on May 1, 2017 and increasing to 600,000 MMBtu/day on May 1, 2020.  These agreements contain firm commitments that are contingent upon the occurrence of certain events, including FERC approval and completion of construction of the pipeline to be built by each of Sabal Trail and Florida Southeast Connection.  See Commitments above.

As of March 31, 2014, NEER has entered into contracts with expiration dates ranging from June 2014 through 2030 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, conversion, enrichment and fabrication of nuclear fuel.  Approximately $2.4 billion of commitments under such contracts 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 and firm transmission service with expiration dates ranging from October 2014 through 2033.

Included in Corporate and Other in the table below is the remaining commitment by a NEECH subsidiary to invest over $900 million in Sabal Trail for the construction of the northern portion of the natural gas pipeline system.  Amounts committed for the remainder of 2014 through 2018 are also included in the estimated capital expenditures table in Commitments above.

The required capacity and/or minimum payments under the contracts discussed above as of March 31, 2014 were estimated as follows:

	Remainder of 2014		2015		2016		2017		2018		Thereafter
	(millions)
FPL:
Capacity charges:(a)
Qualifying facilities	$	210	$	290	$	250	$	255	$	260	$	1,965
JEA and Southern subsidiaries	$	165	$	195	$	70	$	50	$	10	$	5
Minimum charges, at projected prices:(b)
Natural gas, including transportation and storage(c)	$	1,485	$	855	$	685	$	745	$	825	$	14,520
Coal	$	50	$	40	$	20	$	—	$	—	$	—
NEER	$	1,590	$	600	$	175	$	105	$	105	$	475
Corporate and Other(d)(e)	$	130	$	250	$	515	$	50	$	25	$	50

————————————

(a) Capacity charges under these contracts, substantially all of which are recoverable through the capacity cost recovery clause, totaled approximately $123 million and $126 million for the three months ended March 31, 2014 and 2013, respectively.  Energy charges under these contracts, which are recoverable through the fuel clause, totaled approximately $56 million and $23 million for the three months ended March 31, 2014 and 2013, respectively.

(b) Recoverable through the fuel clause.

(c) Includes approximately $200 million, $295 million and $8,535 million in 2017, 2018 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 $50 million commitment to invest in clean power and technology businesses through 2021.

(e) Excludes approximately $320 million and $200 million in 2014 and 2015, respectively, of joint obligations of NEECH and NEER which are included in the NEER amounts above.

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 $375 million of private liability insurance per site, which is the maximum obtainable, and participates in a secondary financial protection system, which provides up to $13.2 billion of liability insurance coverage per incident at any nuclear reactor in the United States.  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 United States, 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 Energy Center (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 $175 million ($106 million for FPL), plus any applicable taxes, in retrospective premiums in a policy year.  NEE and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook, Duane Arnold and St. Lucie Unit No. 2, which approximates $2 million, $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 its transmission and distribution property and has no property insurance coverage for FPL FiberNet's fiber-optic cable.  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 the event of a loss, the amount of insurance available might not be adequate to cover property damage and other expenses incurred.  Uninsured losses and other expenses, to the extent not recovered from customers in the case of FPL or Lone Star Transmission, LLC (Lone Star), would be borne by NEE and/or FPL and/or Lone Star, as the case may be, and could have a material adverse effect on NEE's and FPL's financial condition, results of operations and liquidity.

Spain Solar Projects - On March 28, 2013 and May 3, 2013, events of default occurred under the project-level financing agreements for the Spain solar projects (project-level financing) as a result of changes of law that occurred in December 2012 and February 2013.  These changes of law negatively affected the projected economics of the projects and have caused the project-level financing to be unsupportable by expected future project cash flows.  Under the project-level financing, events of default provide for, among other things, a right by the lenders (which they did not exercise for the project-level financing) to accelerate the payment of the project-level debt.  Accordingly, in 2013, the project-level debt and the associated derivative liabilities related to interest rate swaps were classified as current maturities of long-term debt and current derivative liabilities, respectively, with balances of $792 million and $108 million, respectively, on NEE's condensed consolidated balance sheets as of March 31, 2014. In July 2013, the Spanish government published a new law that created a new economic framework for the Spanish renewable energy sector.  Additional regulatory pronouncements from the Spanish government are needed to complete and implement the framework.  In February 2014, a draft of the regulatory pronouncements was made public. It is uncertain when the final regulatory pronouncements will be issued. At this time, NEE is unable to assess the framework's ultimate impact on the Spain solar projects which could include further impairment of the Spain solar projects and/or a partial refund of tariff revenues collected since July 2013.

As part of a settlement agreement reached on December 20, 2013 between NEECH, NextEra Energy España, S.L. (NEE España), which is the NEER subsidiary in Spain that is the direct shareholder of the project-level subsidiaries, the project-level subsidiaries and the lenders, the future recourse of the lenders under the project-level financing agreements is effectively limited to the letters of credit described below and to the assets of NEE España and the project-level subsidiaries. Under the settlement agreement, the lenders, among other things, irrevocably waived events of default related to changes of law, including those described above, and agreed not to exercise any rights with respect to any additional events of default that may occur with respect to implementing existing changes of law between the settlement date through June 1, 2014 and NEECH affiliates provided for the project-level subsidiaries to post approximately €37 million (approximately $51 million as of March 31, 2014) in letters of credit to fund operating and debt service reserves under the project-level financing agreements and €10 million (approximately $14 million as of March 31, 2014) in a letter of credit to provide support for a performance guarantee under the project-level financing agreements.  Additionally, NEE España, the project-level subsidiaries and the lenders have agreed to use commercially reasonable efforts to seek to restructure the project-level financing on or before June 1, 2014.  There can be no assurance that the project-level financing will be successfully restructured.

Legal Proceedings - In November 1999, the Attorney General of the United States, on behalf of the U.S. Environmental Protection Agency (EPA), brought an action in the U.S. District Court for the Northern District of Georgia against Georgia Power Company and other subsidiaries of The Southern Company for certain alleged violations of the Prevention of Significant Deterioration (PSD) provisions and the New Source Performance Standards (NSPS) of the Clean Air Act.  In May 2001, the EPA amended its complaint to allege, among other things, that Georgia Power Company constructed and is continuing to operate Scherer Unit No. 4, in which FPL owns an interest of approximately 76%, without obtaining a PSD permit, without complying with NSPS requirements, and without applying best available control technology for nitrogen oxides, sulfur dioxides and particulate matter as required by the Clean Air Act.  It also alleges that unspecified major modifications have been made at Scherer Unit No. 4 that require its compliance with the aforementioned Clean Air Act provisions.  The EPA seeks injunctive relief requiring the installation of best available control technology and civil penalties.  Under the EPA's civil penalty rules, the EPA could assess up to $25,000 per day for each violation from an unspecified date after June 1, 1975 through January 30, 1997, up to $27,500 per day for each violation from January 31, 1997 through March 15, 2004, up to $32,500 per day for each violation from March 16, 2004 through January 12, 2009 and up to $37,500 per day for each violation thereafter.  Georgia Power Company has answered the amended complaint, asserting that it has complied with all requirements of the Clean Air Act, denying the plaintiff's allegations of liability, denying that the plaintiff is entitled to any of the relief that it seeks and raising various other defenses.  In June 2001, a federal district court stayed discovery and administratively closed the case and the EPA has not yet moved to reopen the case.  In April 2007, the U.S. Supreme Court in a separate unrelated case rejected an argument that a "major modification" occurs at a plant only when there is a resulting increase in the hourly rate of air emissions.  Georgia Power Company has made a similar argument in defense of its case, but has other factual and legal defenses that are unaffected by the U.S. Supreme Court's decision.

In 1995 and 1996, NEE, through an indirect subsidiary, purchased from Adelphia Communications Corporation (Adelphia) 1,091,524 shares of Adelphia common stock and 20,000 shares of Adelphia preferred stock (convertible into 2,358,490 shares of Adelphia common stock) for an aggregate price of approximately $35,900,000.  On January 29, 1999, Adelphia repurchased all of these shares for $149,213,130 in cash.  In June 2004, Adelphia, Adelphia Cablevision, L.L.C. and the Official Committee of Unsecured Creditors of Adelphia filed a complaint against NEE and its indirect subsidiary in the U.S. Bankruptcy Court, Southern District of New York.  The complaint alleges that the repurchase of these shares by Adelphia was a fraudulent transfer, in that at the time of the transaction Adelphia (i) was insolvent or was rendered insolvent, (ii) did not receive reasonably equivalent value in exchange for the cash it paid, and (iii) was engaged or about to engage in a business or transaction for which any property remaining with Adelphia had unreasonably small capital.  The complaint seeks the recovery for the benefit of Adelphia's bankruptcy estate of the cash paid for the repurchased shares, plus interest from January 29, 1999.  NEE has filed an answer to the complaint.  NEE believes that the complaint is without merit because, among other reasons, Adelphia will be unable to demonstrate that (i) Adelphia's repurchase of shares from NEE, which repurchase was at the market value for those shares, was not for reasonably equivalent value, (ii) Adelphia was insolvent at the time of the repurchase, or (iii) the repurchase left Adelphia with unreasonably small capital.  The trial was completed in May 2012 and closing arguments were heard in July 2012.

In 2004, TXU Portfolio Management Company (TXU) served several NEER affiliates as defendants in a civil action filed in the District Court in Dallas County, Texas.  The petition alleged that the NEER affiliates had contractual obligations to produce and sell to TXU a minimum quantity of energy and renewable energy credits each year during the period from 2002 through 2005 and that the NEER affiliates failed to meet this obligation.  TXU asserted claims for breach of contract and declaratory judgment and sought damages of approximately $34 million plus attorneys' fees, costs and interest.  Following a jury trial in 2007, the trial court issued a final judgment holding that the contracts were not terminated and neither party was entitled to recover any damages, which judgment was appealed by TXU.  In 2010, the appellate court reversed portions of the trial court's judgment, ruling that the contracts' liquidated damage provision is an enforceable liquidated damages clause.  In 2011, the NEER affiliates filed a petition for review of the appellate court decision with the Texas Supreme Court. In March 2014, the Texas Supreme Court, among other things, reversed the appellate court decision by ruling that the liquidated damages clause was an unenforceable penalty.

NEE and FPL are vigorously defending, and believe that they or their affiliates have meritorious defenses to, the lawsuits described above.  In addition to the legal proceedings discussed above, NEE and its subsidiaries, including FPL, are involved in other legal and regulatory proceedings, actions and claims in the ordinary course of their businesses.  Generating plants in which subsidiaries of NEE, including FPL, have an ownership interest are also involved in legal and regulatory proceedings, actions and claims, the liabilities from which, if any, would be shared by such subsidiary.  In the event that NEE and FPL, or their affiliates, do not prevail in the lawsuits described above or these other legal and regulatory proceedings, actions and claims, there may be a material adverse effect on their financial statements.  While management is unable to predict with certainty the outcome of the lawsuits described above or these other legal and regulatory proceedings, actions and claims, based on current knowledge it is not expected that their ultimate resolution, individually or collectively, will have a material adverse effect on the financial statements of NEE or FPL.

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Derivative Instruments (Credit-Risk-Related Contingent Features) (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
Derivative [Line Items]
Fair value of derivative instruments with credit-risk-related contingent features that were in a liability position	$ 1,800,000,000	$ 2,100,000,000
Total required posted collateral should FPL's and Capital Holdings' credit ratings fall to BBB/Baa2	300,000,000	400,000,000
Total required posted collateral should FLP's and Capital Holdings' credit ratings fall below investment grade	2,200,000,000	2,300,000,000
Additional collateral requirements if non-ratings based contract provisions are triggered	800,000,000	800,000,000
Letters of credit posted through the normal course of business that could be applied toward the collateral requirements related to derivative instruments with credit-risk-related contingent features	73,000,000	210,000,000
FPL [Member]
Derivative [Line Items]
Fair value of derivative instruments with credit-risk-related contingent features that were in a liability position	4,000,000	9,000,000
Total required posted collateral should FPL's and Capital Holdings' credit ratings fall to BBB/Baa2	20,000,000	20,000,000
Total required posted collateral should FLP's and Capital Holdings' credit ratings fall below investment grade	400,000,000	400,000,000
Additional collateral requirements if non-ratings based contract provisions are triggered	200,000,000	150,000,000
Letters of credit posted through the normal course of business that could be applied toward the collateral requirements related to derivative instruments with credit-risk-related contingent features	$ 0	$ 0

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Segment Information (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013		Dec. 31, 2013
Segment Reporting Information [Line Items]
OPERATING REVENUES	$ 3,674		$ 3,279
Operating expenses	2,936		2,845
Income (loss) from continuing operations	430		41	[1],[2]
GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	0		231	[1],[2],[3]
Net income (loss)	430		272
Total assets	70,331				69,306
Deemed capital structure of NextEra Energy Resources	70.00%
Impairment charge	0		300
Impairment Of Long Lived Assets Held For Use After Tax			342
NextEra Energy Resources [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,034	[4]	1,016	[4]
Operating expenses	952	[4]	1,149	[4],[5]
Income (loss) from continuing operations	86	[4],[6]	(256)	[1],[4],[6]
GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	0	[4]	216	[1],[3],[4]
Net income (loss)	86	[4],[6]	(40)	[4],[6]
Total assets	30,335				30,154
Corporate and Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	105		75
Operating expenses	81		51
Income (loss) from continuing operations	(3)		9	[1]
GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	0		15	[1],[3]
Net income (loss)	(3)		24
Total assets	2,807				2,664
NextEra Energy Resources [Member]
Segment Reporting Information [Line Items]
Impairment charge			300
Impairment Of Long Lived Assets Held For Use After Tax			342
FPL [Member]
Segment Reporting Information [Line Items]
OPERATING REVENUES	2,535		2,188
Operating expenses	1,903		1,645
GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	0		0
Net income (loss)	347	[7]	288	[7]
Total assets	$ 37,189				$ 36,488

[1] (c)Prior year amounts were restated to conform to current year's presentation. See Note 3 - Nonrecurring Fair Value Measurements.

[2] Certain amounts were restated to conform to current year's presentation. See Note 3 - Nonrecurring Fair Value Measurements

[3] See Note 5.

[4] 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 non-utility interest expense is included in Corporate and Other.

[5] (b)Includes an impairment charge on NEER's Spain solar projects of $300 million. See Note 3 - Nonrecurring Fair Value Measurements.

[6] (d)Includes NEER's tax benefits related to PTCs and in 2013 also includes after-tax charges of $342 million associated with the impairment of the Spain solar projects. See Note 3 - Nonrecurring Fair Value Measurements and Note 4.

[7] (a)FPL's comprehensive income is the same as reported net income.

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Employee Retirement Benefits (Tables)

3 Months Ended

Mar. 31, 2014

Compensation and Retirement Disclosure [Abstract]

Net periodic benefit (income) cost

The components of net periodic benefit (income) cost for the plans are as follows:

	Pension Benefits						Other Benefits
	Three Months Ended   March 31,						Three Months Ended   March 31,
	2014			2013			2014			2013
	(millions)
Service cost	$	16		$	18		$	1		$	1
Interest cost	25			24			4			4
Expected return on plan assets	(60		)	(60		)	—			—
Amortization of prior service cost (benefit)	1			2			(1		)	(1		)
Amortization of losses	—			1			—			1
Net periodic benefit (income) cost at NEE	$	(18	)	$	(15	)	$	4		$	5
Net periodic benefit (income) cost at FPL	$	(11	)	$	(10	)	$	3		$	3

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2014

Commitments and Contingencies [Abstract]

Schedule of Planned Capital Expenditures

At March 31, 2014, estimated capital expenditures for the remainder of 2014 through 2018 were as follows:

	Remainder of 2014		2015		2016		2017		2018		Total
	(millions)
FPL:
Generation:(a)
New(b)(c)	$	475	$	295	$	70	$	—	$	—	$	840
Existing	565		680		610		580		545		2,980
Transmission and distribution	1,055		1,200		1,125		955		1,025		5,360
Nuclear fuel	80		210		220		190		180		880
General and other	130		155		120		165		160		730
Total(d)	$	2,305	$	2,540	$	2,145	$	1,890	$	1,910	$	10,790
NEER:
Wind(e)	$	1,505	$	610	$	25	$	10	$	15	$	2,165
Solar(f)	480		750		520		—		—		1,750
Nuclear(g)	265		275		295		255		265		1,355
Other(h)	345		20		75		40		75		555
Total	$	2,595	$	1,655	$	915	$	305	$	355	$	5,825
Corporate and Other(i)	$	190	$	445	$	795	$	225	$	95	$	1,750

————————————

(a) Includes allowance for funds used during construction (AFUDC) of approximately $28 million, $53 million and $17 million for the remainder of 2014 through 2016, respectively.

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

(c) Consists of projects that have received FPSC approval. Excludes capital expenditures for the construction costs for the two additional nuclear units at FPL's Turkey Point site beyond what is required to receive an NRC license for each unit.

(d) FPL has identified $1.5 billion to $2.5 billion in potential incremental capital expenditures through 2016 in addition to what is included in the table above.

(e) Consists of capital expenditures for new wind projects and related transmission totaling approximately 1,815 MW, including approximately 465 MW in Canada, that have received applicable internal approvals.  NEER expects to add new U.S. wind generation of 2,000 MW to 2,500 MW in 2013 through 2015, including 325 MW added to date, at a total cost of up to $3.5 billion to $4.5 billion.

(f) Consists of capital expenditures for new solar projects and related transmission totaling approximately 600 MW that have received applicable internal approvals, including equity contributions associated with a 50% equity investment in a 550 MW solar project.  Includes approximately $1 billion of total estimated costs associated with the pending acquisition of the development rights for a 250 MW solar project that is expected to close in mid-2014, subject to certain conditions precedent, and construction of the project, which is expected to be completed in 2016.  Excludes solar projects requiring internal approvals with generation totaling 47 MW with an estimated cost of approximately $120 million.

(g) Includes nuclear fuel.

(h) Consists of capital expenditures that have received applicable internal approvals.

(i) Includes capital expenditures totaling approximately $1.4 billion for the remainder of 2014 through 2018 for construction of a natural gas pipeline system that has received applicable internal approvals, including approximately $885 million of equity contributions associated with a 33% equity investment in the northern portion of the natural gas pipeline system and $525 million for the southern portion, which includes AFUDC of approximately $1 million, $7 million, $20 million and $12 million for the remainder of 2014 through 2017, respectively.  The natural gas pipeline system is subject to certain conditions, including FERC approval.  A FERC decision is expected in 2015. See Contracts below.

Required capacity and/or minimum payments under contracts

The required capacity and/or minimum payments under the contracts discussed above as of March 31, 2014 were estimated as follows:

	Remainder of 2014		2015		2016		2017		2018		Thereafter
	(millions)
FPL:
Capacity charges:(a)
Qualifying facilities	$	210	$	290	$	250	$	255	$	260	$	1,965
JEA and Southern subsidiaries	$	165	$	195	$	70	$	50	$	10	$	5
Minimum charges, at projected prices:(b)
Natural gas, including transportation and storage(c)	$	1,485	$	855	$	685	$	745	$	825	$	14,520
Coal	$	50	$	40	$	20	$	—	$	—	$	—
NEER	$	1,590	$	600	$	175	$	105	$	105	$	475
Corporate and Other(d)(e)	$	130	$	250	$	515	$	50	$	25	$	50

————————————

(a) Capacity charges under these contracts, substantially all of which are recoverable through the capacity cost recovery clause, totaled approximately $123 million and $126 million for the three months ended March 31, 2014 and 2013, respectively.  Energy charges under these contracts, which are recoverable through the fuel clause, totaled approximately $56 million and $23 million for the three months ended March 31, 2014 and 2013, respectively.

(b) Recoverable through the fuel clause.

(c) Includes approximately $200 million, $295 million and $8,535 million in 2017, 2018 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 $50 million commitment to invest in clean power and technology businesses through 2021.

(e) Excludes approximately $320 million and $200 million in 2014 and 2015, respectively, of joint obligations of NEECH and NEER which are included in the NEER amounts above.

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Commitments and Contingencies (Spain Solar Projects) (Details) In Millions, unless otherwise specified	Mar. 31, 2014 NextEra Energy Resources [Member] USD ($)	Mar. 31, 2014 Standby Letters of Credit [Member] Capital Holdings [Member] USD ($)	Mar. 31, 2014 Standby Letters of Credit [Member] Capital Holdings [Member] EUR (€)	Mar. 31, 2014 Performance Guarantee [Member] Capital Holdings [Member] USD ($)	Mar. 31, 2014 Performance Guarantee [Member] Capital Holdings [Member] EUR (€)
Loss Contingencies [Line Items]
Letters of Credit Outstanding, Amount		$ 51	€ 37	$ 14	€ 10
Amount of debt outstanding under financing agreements related to Spain solar projects	792
Amount of noncurrent derivative liability classified as current derivative liability due to event of default	$ 108

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Income Taxes (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Income Tax Disclosure [Abstract]
Effective income tax rate (as a percent)	26.00%	78.00%
Valuation Allowances and Reserves, Charged to Cost and Expense		$ 132
Impairment of Long-Lived Assets Held-for-use	0	300
Impairment Of Long Lived Assets Held For Use After Tax		342
Production tax credits	49	59
Deferred income tax benefit associated with convertible investment tax credits	$ 12	$ 13

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CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) (USD $) In Millions, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
PROPERTY, PLANT AND EQUIPMENT
Electric plant in service and other property	$ 63,428	$ 62,699
Nuclear fuel	2,166	2,059
Construction work in progress	4,773	4,690
Less accumulated depreciation and amortization	(17,061)	(16,728)
Total property, plant and equipment - net ($5,077 and $5,127 related to VIEs, respectively)	53,306	52,720
CURRENT ASSETS
Cash and cash equivalents	488	438
Customer receivables, net of allowances	1,904	1,777
Other receivables	647	512
Materials, supplies and fossil fuel inventory	1,148	1,153
Regulatory assets:
Deferred clause and franchise expenses	166	192
Other	116	116
Derivatives	533	498
Deferred income taxes	754	753
Other	385	403
Total current assets	6,141	5,842
OTHER ASSETS
Special use funds	4,866	4,780
Other investments	1,148	1,121
Prepaid benefit costs	1,476	1,456
Regulatory assets:
Securitized storm-recovery costs ($220 and $228 related to a VIE, respectively)	358	372
Other	440	426
Derivatives	984	1,163
Other	1,612	1,426
Total other assets	10,884	10,744
TOTAL ASSETS	70,331	69,306
CAPITALIZATION
Common stock	4	4
Additional paid-in capital	6,451	6,411
Retained earnings	11,684	11,569
Accumulated other comprehensive income	21	56
Total common shareholder's equity	18,160	18,040
Long-term debt	23,824	23,969
Total capitalization	41,984	42,009
CURRENT LIABILITIES
Commercial paper	1,869	691
Current maturities of long-term debt	3,822	3,766
Accounts payable	1,450	1,200
Customer deposits	452	452
Accrued interest and taxes	555	473
Derivatives	815	838
Accrued construction-related expenditures	458	839
Other	871	930
Total current liabilities	10,292	9,189
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,877	1,850
Deferred income taxes	8,306	8,144
Regulatory liabilities:
Accrued asset removal costs	1,722	1,839
Asset retirement obligation regulatory expense difference	2,122	2,082
Other	457	462
Derivatives	396	473
Deferral related to differential membership interests - VIEs	1,933	2,001
Other	1,242	1,257
Total other liabilities and deferred credits	18,055	18,108
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	70,331	69,306
FPL [Member]
ELECTRIC UTILITY PLANT
Plant in service and other property	37,132	36,838
Nuclear fuel	1,329	1,240
Construction work in progress	2,241	1,818
Less accumulated depreciation and amortization	(11,085)	(10,944)
Total electric utility plant - net	29,617	28,952
CURRENT ASSETS
Cash and cash equivalents	38	19
Customer receivables, net of allowances	706	757
Other receivables	111	137
Materials, supplies and fossil fuel inventory	764	742
Regulatory assets:
Deferred clause and franchise expenses	166	192
Other	107	105
Other	237	261
Total current assets	2,129	2,213
OTHER ASSETS
Special use funds	3,327	3,273
Prepaid benefit costs	1,154	1,142
Regulatory assets:
Securitized storm-recovery costs ($220 and $228 related to a VIE, respectively)	358	372
Other	407	396
Other	197	140
Total other assets	5,443	5,323
TOTAL ASSETS	37,189	36,488
CAPITALIZATION
Common stock	1,373	1,373
Additional paid-in capital	6,278	6,179
Retained earnings	5,879	5,532
Total common shareholder's equity	13,530	13,084
Long-term debt	8,443	8,473
Total capitalization	21,973	21,557
CURRENT LIABILITIES
Commercial paper	324	204
Current maturities of long-term debt	358	356
Accounts payable	691	611
Customer deposits	447	447
Accrued interest and taxes	382	272
Accrued construction-related expenditures	150	202
Other	419	438
Total current liabilities	2,771	2,530
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,302	1,285
Deferred income taxes	6,444	6,355
Regulatory liabilities:
Accrued asset removal costs	1,722	1,839
Asset retirement obligation regulatory expense difference	2,122	2,082
Other	387	386
Other	468	454
Total other liabilities and deferred credits	12,445	12,401
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$ 37,189	$ 36,488

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Fair Value Measurements

3 Months Ended

Mar. 31, 2014

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 their 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 - Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less.  NEE primarily holds investments in money market funds.  The fair value of these funds is calculated using current 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 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 swaps to mitigate and adjust interest rate and foreign currency exposure related to certain outstanding and forecasted 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 a discounted cash flows valuation technique based on 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:

	March 31, 2014
	Level 1		Level 2			Level 3		Netting(a)			Total
	(millions)
Assets:
Cash equivalents:
NEE - equity securities	$	84	$	—		$	—	$	—		$	84
Special use funds:(b)
NEE:
Equity securities	$	1,235	$	1,290	(c)	$	—	$	—		$	2,525
U.S. Government and municipal bonds	$	617	$	166		$	—	$	—		$	783
Corporate debt securities	$	—	$	612		$	—	$	—		$	612
Mortgage-backed securities	$	—	$	514		$	—	$	—		$	514
Other debt securities	$	25	$	44		$	—	$	—		$	69
FPL:
Equity securities	$	366	$	1,128	(c)	$	—	$	—		$	1,494
U.S. Government and municipal bonds	$	520	$	147		$	—	$	—		$	667
Corporate debt securities	$	—	$	427		$	—	$	—		$	427
Mortgage-backed securities	$	—	$	438		$	—	$	—		$	438
Other debt securities	$	25	$	25		$	—	$	—		$	50
Other investments:
NEE:
Equity securities	$	44	$	—		$	—	$	—		$	44
Debt securities	$	21	$	103		$	—	$	—		$	124
Derivatives:
NEE:
Commodity contracts	$	1,529	$	1,989		$	1,035	$	(3,112	)	$	1,441	(d)
Interest rate contracts	$	—	$	76		$	—	$	—		$	76	(d)
FPL - commodity contracts	$	—	$	119		$	4	$	7		$	130	(d)
Liabilities:
Derivatives:
NEE:
Commodity contracts	$	1,434	$	1,804		$	467	$	(2,871	)	$	834	(d)
Interest rate contracts	$	—	$	125		$	108	$	—		$	233	(d)
Foreign currency swaps	$	—	$	144		$	—	$	—		$	144	(d)
FPL - commodity contracts	$	—	$	2		$	1	$	7		$	10	(d)

————————————

(a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and 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 condensed consolidated balance sheets and are recorded in customer receivables - net and accounts payable, respectively.

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

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

(d) See Note 2 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's condensed consolidated balance sheets.

	December 31, 2013
	Level 1		Level 2			Level 3		Netting(a)			Total
	(millions)
Assets:
Cash equivalents:
NEE - equity securities	$	20	$	—		$	—	$	—		$	20
Special use funds:(b)
NEE:
Equity securities	$	1,170	$	1,336	(c)	$	—	$	—		$	2,506
U.S. Government and municipal bonds	$	647	$	180		$	—	$	—		$	827
Corporate debt securities	$	—	$	597		$	—	$	—		$	597
Mortgage-backed securities	$	—	$	479		$	—	$	—		$	479
Other debt securities	$	16	$	44		$	—	$	—		$	60
FPL:
Equity securities	$	291	$	1,176	(c)	$	—	$	—		$	1,467
U.S. Government and municipal bonds	$	584	$	154		$	—	$	—		$	738
Corporate debt securities	$	—	$	421		$	—	$	—		$	421
Mortgage-backed securities	$	—	$	401		$	—	$	—		$	401
Other debt securities	$	16	$	30		$	—	$	—		$	46
Other investments:
NEE:
Equity securities	$	51	$	—		$	—	$	—		$	51
Debt securities	$	11	$	107		$	—	$	—		$	118
Derivatives:
NEE:
Commodity contracts	$	1,368	$	2,106		$	1,069	$	(2,972	)	$	1,571	(d)
Interest rate contracts	$	—	$	90		$	—	$	—		$	90	(d)
FPL - commodity contracts	$	—	$	53		$	2	$	(7	)	$	48	(d)
Liabilities:
Derivatives:
NEE:
Commodity contracts	$	1,285	$	1,994		$	354	$	(2,693	)	$	940	(d)
Interest rate contracts	$	—	$	127		$	93	$	—		$	220	(d)
Foreign currency swaps	$	—	$	151		$	—	$	—		$	151	(d)
FPL - commodity contracts	$	—	$	7		$	2	$	(7	)	$	2	(d)

————————————

(a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and 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 condensed consolidated balance sheets and are recorded in customer receivables - net and accounts payable, respectively.

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

(c) At NEE, approximately $1,300 million ($1,141 million at FPL) are invested in commingled funds whose underlying securities would be Level 1 if those securities were held directly by NEE or FPL.

(d) See Note 2 - Fair Value of Derivative Instruments for a reconciliation of net derivatives to NEE's and FPL's condensed 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 critically 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 March 31, 2014 are as follows:

Transaction Type	Fair Value at March 31, 2014				Valuation Technique(s)	Significant Unobservable Inputs	Range
	Assets		Liabilities
	(millions)
Forward contracts - power	$	605	$	106	Discounted cash flow	Forward price (per MWh)	$9	—	$156
Forward contracts - gas	96		44		Discounted cash flow	Forward price (per MMBtu)	$2	—	$16
Forward contracts - other commodity related	23		16		Discounted cash flow	Forward price (various)	$1	—	$245
Options - power	79		84		Option models	Implied correlations	7%	—	96%
						Implied volatilities	1%	—	271%
Options - gas	34		57		Option models	Implied correlations	7%	—	96%
						Implied volatilities	1%	—	70%
Full requirements and unit contingent contracts	198		160		Discounted cash flow	Forward price (per MWh)	$(10)	—	$203
						Customer migration rate(a)	—%	—	20%
Total	$	1,035	$	467

——————————

(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 swap liabilities related to the solar projects in Spain of approximately $108 million at March 31, 2014 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 swap agreements.

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

	Three Months Ended March 31,
	2014						2013
	NEE			FPL			NEE			FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at December 31	$	622		$	—		$	566		$	2
Realized and unrealized gains (losses):
Included in earnings(a)	(423		)	—			(3		)	—
Included in regulatory assets and liabilities	4			4			1			1
Purchases	4			—			49			—
Settlements	266			(1		)	(33		)	(1		)
Issuances	(19		)	—			(64		)	—
Transfers in(b)	7			—			—			—
Transfers out(b)	(1		)	—			6			—
Fair value of net derivatives based on significant unobservable inputs at March 31	$	460		$	3		$	522		$	2
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)	$	(249	)	$	—		$	32		$	—

————————————

(a) For the three months ended March 31, 2014, realized and unrealized losses of approximately $405 million are reflected in the condensed consolidated statements of income in operating revenues, $15 million in interest expense and the balance is reflected in fuel, purchased power and interchange.  For the three months ended March 31, 2013, realized and unrealized losses are reflected in the condensed consolidated statements of income in fuel, purchased power and interchange.

(b) Transfers into Level 3 were a result of decreased observability of market data and transfers from Level 3 to Level 2 were a result of increased observability of market data.  NEE's and FPL's policy is to recognize all transfers at the beginning of the reporting period.

(c) For the three months ended March 31, 2014, unrealized losses of $234 million are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in interest expense.  For the three months ended March 31, 2013, unrealized gains of approximately $31 million are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

Nonrecurring Fair Value Measurements - NEE tests long-lived assets for recoverability whenever events or changes in circumstances indicate that the carrying amount may not be recoverable.  In February 2013, the Spanish government enacted a new law that made further changes to the economic framework of renewable energy projects including, among other things, changes that negatively affect the projected economics of the 99.8 MW of solar thermal facilities that affiliates of NEER were constructing in Spain (Spain solar projects) (see Note 9 - Spain Solar Projects).  Due to the February 2013 change in law, NEER performed a recoverability analysis, considering, among other things, working with lenders to restructure the financing agreements, abandoning the projects or selling the projects, and concluded that the undiscounted cash flows of the Spain solar projects were less than the carrying value of the projects.  Accordingly, NEER performed a fair value analysis based on the income approach to determine the amount of the impairment.  Based on the fair value analysis, property, plant and equipment with a carrying amount of approximately $800 million were written down to their estimated fair value of approximately $500 million as of March 31, 2013, resulting in an impairment of $300 million (which is recorded as a separate line item in NEE’s condensed consolidated statements of income for the three months ended March 31, 2013) and other related charges ($342 million after-tax, see Note 4).

The estimate of the fair value was based on the discounted cash flows which were determined using a market participant view of the Spain solar projects upon completion and final commissioning of the projects.  As part of the valuation, NEER used observable inputs where available, including the revised renewable energy pricing under the February 2013 change in law.  Significant unobservable inputs (Level 3), including forecasts of generation, estimates of tariff escalation rates and estimated costs of debt and equity capital, were also used in the estimation of fair value.  In addition, NEER made certain assumptions regarding the projected capital and maintenance expenditures based on the estimated costs to complete the Spain solar projects and ongoing capital and maintenance expenditures.  An increase in the revenue and generation forecasts, a decrease in the projected capital and maintenance expenditures or a decrease in the weighted-average cost of capital each would result in an increased fair market value.  Changes in the opposite direction of those unobservable inputs would result in a decreased fair market value.  See Note 9 - Spain Solar Projects for a discussion of additional developments that could potentially impact the Spain solar projects.

In March 2013, NEER initiated a plan and received internal authorization to pursue the sale of its ownership interests in Maine fossil.  In connection with the decision to sell Maine fossil, a loss of approximately $67 million ($43 million after-tax) was originally reflected in net gain from discontinued operations, net of income taxes in NEE's condensed consolidated statements of income for the three months ended March 31, 2013.  The fair value measurement (Level 3) was based on the estimated sales price less the estimated costs to sell.  The estimated sales price was estimated using an income approach based primarily on capacity revenue forecasts.  In March 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). The fair value measurement (Level 3) was estimated using an income approach based primarily on the updated capacity revenue forecasts. Based on NEER's decision to retain Maine fossil, the $67 million loss recorded during the three months ended March 31, 2013 was reclassified from discontinued operations to income from continuing operations and together with the $21 million gain recorded during the three months ended March 31, 2014 are included as a separate line item in NEE's condensed consolidated statements of income. The carrying amount of the assets and liabilities and the operations of Maine fossil for all periods presented were not material.

Fair Value of Financial Instruments Recorded at the Carrying Amount - The carrying amounts of cash equivalents, short-term debt and commercial paper approximate their fair values.  The carrying amounts and estimated fair values of other financial instruments, excluding those recorded at fair value and disclosed above in Recurring Fair Value Measurements, are as follows:

	March 31, 2014					December 31, 2013
	Carrying Amount		Estimated Fair Value			Carrying Amount		Estimated Fair Value
	(millions)
NEE:
Special use funds(a)	$	363	$	363		$	311	$	311
Other investments - primarily notes receivable	$	528	$	667	(b)	$	531	$	627	(b)
Long-term debt, including current maturities	$	27,639	$	28,782	(c)	$	27,728	$	28,612	(c)
FPL:
Special use funds(a)	$	251	$	251		$	200	$	200
Long-term debt, including current maturities	$	8,801	$	9,384	(c)	$	8,829	$	9,451	(c)

————————————

(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 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.  As of March 31, 2014 and December 31, 2013, NEE had no notes receivable reported in non-accrual status.

(c) As of March 31, 2014 and December 31, 2013, for NEE, $18,135 million and $17,921 million, respectively, is estimated using quoted market prices for the same or similar issues (Level 2); the balance is estimated using a discounted cash flow valuation technique, considering the current credit spread of the debtor (Level 3).  For FPL, 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) consist of FPL's storm fund assets of $75 million and NEE's and FPL's nuclear decommissioning fund assets of $4,791 million and $3,252 million, respectively, at March 31, 2014.  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 $1,941 million and $1,420 million, respectively, at March 31, 2014 and $1,954 million and $1,384 million, respectively, at December 31, 2013 ($1,550 million and $714 million, respectively, at March 31, 2014 and $1,595 million and $694 million, respectively, at December 31, 2013 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 and included in other - net in NEE's condensed consolidated statements of income.  Debt securities included in the nuclear decommissioning funds have a weighted-average maturity at March 31, 2014 of approximately six years at both NEE and FPL.  FPL's storm fund primarily consists of debt securities with a weighted-average maturity at March 31, 2014 of approximately three years.  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
	Three Months Ended   March 31,				Three Months Ended   March 31,
	2014		2013		2014		2013
	(millions)
Realized gains	$	77	$	42	$	32	$	23
Realized losses	$	22	$	30	$	17	$	22
Proceeds from sale or maturity of securities	$	1,401	$	924	$	1,162	$	685

The unrealized gains on available for sale securities are as follows:

	NEE				FPL
	March 31, 2014		December 31, 2013		March 31, 2014		December 31, 2013
	(millions)
Equity securities	$	1,105	$	1,125	$	780	$	777
Debt securities	$	49	$	42	$	41	$	36

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
	March 31, 2014		December 31, 2013		March 31, 2014		December 31, 2013
	(millions)
Unrealized losses(a)	$	12	$	32	$	10	$	25
Fair value	$	660	$	1,069	$	516	$	844

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(a) Unrealized losses on available for sale debt securities for securities in an unrealized loss position for greater than twelve months at March 31, 2014 and December 31, 2013 were not material to NEE or FPL.

Regulations issued by the Federal Energy Regulatory Commission (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 NEER's Seabrook Station (Seabrook), decommissioning fund contributions and withdrawals are also regulated by the Nuclear Decommissioning Financing Committee 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.

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Segment Information (Tables)

3 Months Ended

Mar. 31, 2014

Segment Reporting [Abstract]

Segment information

	Three Months Ended March 31,
	2014										2013
	FPL		NEER(a)			Corporate and Other			NEE Consoli- dated		FPL		NEER(a)				Corporate and Other		NEE Consoli- dated
									(millions)
Operating revenues	$	2,535	$	1,034		$	105		$	3,674	$	2,188	$	1,016			$	75	$	3,279
Operating expenses	$	1,903	$	952		$	81		$	2,936	$	1,645	$	1,149		(b)	$	51	$	2,845
Income (loss) from continuing operations(c)	$	347	$	86	(d)	$	(3	)	$	430	$	288	$	(256	)	(d)	$	9	$	41
Gain from discontinued operations, net of income taxes(c)(e)	$	—	$	—		$	—		$	—	$	—	$	216			$	15	$	231
Net income (loss)	$	347	$	86	(d)	$	(3	)	$	430	$	288	$	(40	)	(d)	$	24	$	272

————————————

(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 non-utility interest expense is included in Corporate and Other.

(b) Includes an impairment charge on NEER's Spain solar projects of $300 million.  See Note 3 - Nonrecurring Fair Value Measurements.

(c) Prior year amounts were restated to conform to current year's presentation.  See Note 3 - Nonrecurring Fair Value Measurements.

(d) Includes NEER's tax benefits related to PTCs and in 2013 also includes after-tax charges of $342 million associated with the impairment of the Spain solar projects.  See Note 3 - Nonrecurring Fair Value Measurements and Note 4.

(e) See Note 5.

	March 31, 2014								December 31, 2013
	FPL		NEER		Corporate and Other		NEE Consoli- dated		FPL		NEER		Corporate and Other		NEE Consoli- dated
							(millions)
Total assets	$	37,189	$	30,335	$	2,807	$	70,331	$	36,488	$	30,154	$	2,664	$	69,306

XML

Fair Value Measurements (Nonrecurring Fair Value Measurements) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gain (loss) on assets previously held for sale	$ 21	$ (67)
Impairment of Long-Lived Assets Held-for-use	0	300
Impairment Of Long Lived Assets Held For Use After Tax		342
NextEra Energy Resources [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Planned capacity of Spain Solar projects - in megawatts		99.8
Carrying value of property, plant, and equipment prior to impairment charge		800
Property, Plant, and Equipment, Fair Value Disclosure		500
Impairment of Long-Lived Assets Held-for-use		300
Impairment Of Long Lived Assets Held For Use After Tax		342
Maine fossil [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gain (loss) on assets previously held for sale	21	(67)
After-tax gain (loss) on assets previously held for sale	$ 12	$ (43)
Capacity associated with assets previously held for sale (in megawatts)	796

XML

Fair Value Measurements (Policies)

3 Months Ended

Mar. 31, 2014

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments, Policy [Policy Text Block]

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 their 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 - Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less.  NEE primarily holds investments in money market funds.  The fair value of these funds is calculated using current 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 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 swaps to mitigate and adjust interest rate and foreign currency exposure related to certain outstanding and forecasted 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 a discounted cash flows valuation technique based on the net amount of estimated future cash inflows and outflows related to the agreements.