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 endedSeptember 30, 2012

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 (or for such shorter period that the registrants were required to submit and post such files).

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 September 30, 2012: 423,206,077 shares.

As of September 30, 2012, 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	56
Item 4.	Controls and Procedures	56
	PART II - OTHER INFORMATION
Item 1.	Legal Proceedings	56
Item 1A.	Risk Factors	56
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	56
Item 5.	Other Information	57
Item 6.	Exhibits	58
Signatures		59

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, 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.

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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 will, will likely result, are expected to, will continue, is anticipated, aim, believe, 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 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 (RPS) 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 (Dodd-Frank Act) broaden the scope of its provisions regarding the regulation of over-the-counter (OTC) financial derivatives and make them applicable to NEE and FPL.

• NEE and FPL are subject to numerous environmental laws and regulations that require capital expenditures, increase their cost of operations and may expose them to liabilities.

• 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

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material adverse effect on 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 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 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 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 hedge effectively its assets or positions against changes in commodity prices, volumes, interest rates, counterparty credit risk or other risk measures could significantly impair NEE's results of operations.

• 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.

• If price movements significantly or persistently deviate from historical behavior, NEE's and FPL's hedging and trading procedures and associated risk management tools 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 an 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 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.

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• 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 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 and FPL's defined benefit pension plan's funded status, which may materially adversely affect NEE's and FPL's liquidity and results of operations.

• 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 adversely affect NEE's liquidity and financial results.

• 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, 2011 (2011 Form 10-K) and Part II, Item 1A. Risk Factors in NEE's and FPL's Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2012 (March 2012 Form 10-Q), and investors should refer to those sections of the 2011 Form 10-K and the March 2012 Form 10-Q.  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 September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
OPERATING REVENUES	$	3,843		$	4,382		$	10,881		$	11,476
OPERATING EXPENSES
Fuel, purchased power and interchange	1,526			1,911			3,943			4,872
Other operations and maintenance	776			748			2,347			2,212
Impairment charges	—			—			—			51
Depreciation and amortization	467			496			1,121			1,236
Taxes other than income taxes and other	325			316			855			859
Total operating expenses	3,094			3,471			8,266			9,230
OPERATING INCOME	749			911			2,615			2,246
OTHER INCOME (DEDUCTIONS)
Interest expense	(259		)	(265		)	(795		)	(775		)
Loss on natural gas-fired generating assets held for sale	—			(148		)	—			(148		)
Equity in earnings of equity method investees	16			28			17			57
Allowance for equity funds used during construction	21			7			52			28
Interest income	20			21			62			58
Gains on disposal of assets - net	53			37			120			79
Other than temporary impairment losses on securities held in nuclear decommissioning funds	(4		)	(30		)	(11		)	(34		)
Other - net	(27		)	4			(25		)	18
Total other deductions - net	(180		)	(346		)	(580		)	(717		)
INCOME BEFORE INCOME TAXES	569			565			2,035			1,529
INCOME TAXES	154			158			553			273
NET INCOME	$	415		$	407		$	1,482		$	1,256
Earnings per share of common stock:
Basic	$	0.99		$	0.98		$	3.57		$	3.01
Assuming dilution	$	0.98		$	0.97		$	3.55		$	3.00
Dividends per share of common stock	$	0.60		$	0.55		$	1.80		$	1.65
Weighted-average number of common shares outstanding:
Basic	419.3			417.4			415.6			416.7
Assuming dilution	421.7			419.8			418.0			419.1

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 2011 Form 10-K.

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NEXTERA ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(millions)

(unaudited)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
NET INCOME	$	415		$	407		$	1,482		$	1,256
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX
Net unrealized gains (losses) on cash flow hedges:
Effective portion of net unrealized losses (net of $15, $92, $41 and $125 tax benefit, respectively)	(30		)	(158		)	(79		)	(248		)
Reclassification from accumulated other comprehensive income to net income (net of $7, $10, $18 and $18 tax expense, respectively)	3			16			24			36
Net unrealized gains (losses) on available for sale securities:
Net unrealized gains (losses) on securities still held (net of $18 tax expense, $27 tax benefit, $44 tax expense and $12 tax benefit, respectively)	26			(43		)	64			(20		)
Reclassification from accumulated other comprehensive income to net income (net of $18, $17, $43 and $32 tax benefit, respectively)	(27		)	(25		)	(64		)	(47		)
Defined benefit pension and other benefits plans (net of $3 tax benefit and $4 tax expense, respectively)	—			—			(6		)	6
Net unrealized gains (losses) on foreign currency translation (net of $2 tax expense, $10 tax benefit, $3 tax expense and $4 tax benefit, respectively)	3			(19		)	6			(7		)
Other comprehensive loss related to equity method investee (net of $3 and $7 tax benefit, respectively)	(4		)	—			(10		)	—
Total other comprehensive loss, net of tax	(29		)	(229		)	(65		)	(280		)
COMPREHENSIVE INCOME	$	386		$	178		$	1,417		$	976

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2011 Form 10-K.

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NEXTERA ENERGY, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(millions, except par value)

(unaudited)

	September 30, 2012			December 31, 2011
PROPERTY, PLANT AND EQUIPMENT
Electric utility plant in service and other property	$	54,262		$	50,768
Nuclear fuel	1,994			1,795
Construction work in progress	7,174			4,989
Less accumulated depreciation and amortization	(15,737		)	(15,062		)
Total property, plant and equipment - net ($3,900 and $3,063 related to VIEs, respectively)	47,693			42,490
CURRENT ASSETS
Cash and cash equivalents	246			377
Customer receivables, net of allowances of $14 and $11, respectively	1,633			1,372
Other receivables	489			430
Materials, supplies and fossil fuel inventory	1,055			1,074
Regulatory assets:
Deferred clause and franchise expenses	54			112
Derivatives	59			502
Other	87			84
Derivatives	482			611
Other	332			310
Total current assets	4,437			4,872
OTHER ASSETS
Special use funds	4,223			3,867
Other investments	971			907
Prepaid benefit costs	1,093			1,021
Regulatory assets:
Securitized storm-recovery costs ($284 and $317 related to a VIE, respectively)	462			517
Other	524			621
Derivatives	944			973
Other	1,702			1,920
Total other assets	9,919			9,826
TOTAL ASSETS	$	62,049		$	57,188
CAPITALIZATION
Common stock ($0.01 par value, authorized shares - 800; outstanding shares - 423 and 416, respectively)	$	4		$	4
Additional paid-in capital	5,494			5,217
Retained earnings	10,607			9,876
Accumulated other comprehensive loss	(219		)	(154		)
Total common shareholders' equity	15,886			14,943
Long-term debt ($1,301 and $1,364 related to VIEs, respectively)	22,714			20,810
Total capitalization	38,600			35,753
CURRENT LIABILITIES
Commercial paper	1,053			1,349
Short-term debt	521			—
Current maturities of long-term debt	2,062			808
Accounts payable	1,194			1,191
Customer deposits	513			547
Accrued interest and taxes	703			464
Derivatives	486			1,090
Accrued construction-related expenditures	512			518
Other	831			752
Total current liabilities	7,875			6,719
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,685			1,611
Accumulated deferred income taxes	6,166			5,681
Regulatory liabilities:
Accrued asset removal costs	2,017			2,197
Asset retirement obligation regulatory expense difference	1,814			1,640
Other	361			419
Derivatives	530			541
Deferral related to differential membership interests - VIEs	1,498			1,203
Other	1,503			1,424
Total other liabilities and deferred credits	15,574			14,716
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	62,049		$	57,188

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2011 Form 10-K.

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NEXTERA ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(millions)

(unaudited)

	Nine Months Ended September 30,
	2012			2011
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	1,482		$	1,256
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	1,121			1,236
Nuclear fuel amortization	194			210
Loss on natural gas-fired generating assets held for sale	—			148
Impairment charges	—			51
Unrealized losses (gains) on marked to market energy contracts	(89		)	182
Deferred income taxes	517			274
Cost recovery clauses and franchise fees	115			71
Changes in prepaid option premiums and derivative settlements	(36		)	23
Equity in earnings of equity method investees	(17		)	(57		)
Distributions of earnings from equity method investees	20			67
Allowance for equity funds used during construction	(52		)	(28		)
Gains on disposal of assets - net	(120		)	(79		)
Other than temporary impairment losses on securities held in nuclear decommissioning funds	11			34
Other - net	236			121
Changes in operating assets and liabilities:
Customer receivables	(255		)	(228		)
Other receivables	(92		)	56
Materials, supplies and fossil fuel inventory	21			(269		)
Other current assets	(51		)	(27		)
Other assets	(50		)	(83		)
Accounts payable	1			30
Customer deposits	(34		)	5
Margin cash collateral	110			(28		)
Income taxes	(6		)	106
Interest and other taxes	270			259
Other current liabilities	(27		)	(83		)
Other liabilities	(112		)	(130		)
Net cash provided by operating activities	3,157			3,117
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL	(3,061		)	(2,128		)
Independent power and other investments of NEER	(3,025		)	(1,654		)
Cash grants under the American Recovery and Reinvestment Act of 2009	105			503
Nuclear fuel purchases	(202		)	(331		)
Other capital expenditures	(401		)	(204		)
Change in loan proceeds restricted for construction	212			(596		)
Proceeds from sale or maturity of securities in special use funds	3,890			3,567
Purchases of securities in special use funds	(3,994		)	(3,638		)
Proceeds from sale or maturity of other securities	219			399
Purchases of other securities	(259		)	(431		)
Other - net	15			91
Net cash used in investing activities	(6,501		)	(4,422		)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	4,226			2,917
Retirements of long-term debt	(1,321		)	(1,688		)
Proceeds from sale of differential membership interests	414			210
Payments to differential membership investors	(53		)	—
Net change in short-term debt	396			946
Issuances of common stock - net	386			39
Repurchases of common stock	(19		)	—
Dividends on common stock	(752		)	(689		)
Other - net	(64		)	(92		)
Net cash provided by financing activities	3,213			1,643
Net increase (decrease) in cash and cash equivalents	(131		)	338
Cash and cash equivalents at beginning of period	377			302
Cash and cash equivalents at end of period	$	246		$	640
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	$	943		$	851

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2011 Form 10-K.

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FLORIDA POWER & LIGHT COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(millions)

(unaudited)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
OPERATING REVENUES	$	2,975		$	3,152		$	7,778		$	8,200
OPERATING EXPENSES
Fuel, purchased power and interchange	1,280			1,479			3,301			3,854
Other operations and maintenance	427			429			1,305			1,237
Depreciation and amortization	254			299			496			653
Taxes other than income taxes and other	295			289			814			822
Total operating expenses	2,256			2,496			5,916			6,566
OPERATING INCOME	719			656			1,862			1,634
OTHER INCOME (DEDUCTIONS)
Interest expense	(104		)	(101		)	(314		)	(287		)
Allowance for equity funds used during construction	14			6			36			26
Other - net	—			1			—			(2		)
Total other deductions - net	(90		)	(94		)	(278		)	(263		)
INCOME BEFORE INCOME TAXES	629			562			1,584			1,371
INCOME TAXES	237			215			600			519
NET INCOME(a)	$	392		$	347		$	984		$	852

__________________________________

(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 2011 Form 10-K.

10

FLORIDA POWER & LIGHT COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

(millions, except share amount)

(unaudited)

	September 30, 2012			December 31, 2011
ELECTRIC UTILITY PLANT
Plant in service and other property	$	33,981		$	31,564
Nuclear fuel	1,148			1,005
Construction work in progress	2,492			2,601
Less accumulated depreciation and amortization	(10,915		)	(10,916		)
Total electric utility plant - net	26,706			24,254
CURRENT ASSETS
Cash and cash equivalents	20			36
Customer receivables, net of allowances of $10 and $8, respectively	986			682
Other receivables	239			312
Materials, supplies and fossil fuel inventory	736			759
Regulatory assets:
Deferred clause and franchise expenses	54			112
Derivatives	59			502
Other	83			80
Other	132			166
Total current assets	2,309			2,649
OTHER ASSETS
Special use funds	2,967			2,737
Prepaid benefit costs	1,124			1,088
Regulatory assets:
Securitized storm-recovery costs ($284 and $317 related to a VIE, respectively)	462			517
Other	336			395
Other	216			176
Total other assets	5,105			4,913
TOTAL ASSETS	$	34,120		$	31,816
CAPITALIZATION
Common stock (no par value, 1,000 shares authorized, issued and outstanding)	$	1,373		$	1,373
Additional paid-in capital	5,703			5,464
Retained earnings	4,998			4,013
Total common shareholder's equity	12,074			10,850
Long-term debt ($386 and $437 related to a VIE, respectively)	7,632			7,483
Total capitalization	19,706			18,333
CURRENT LIABILITIES
Commercial paper	472			330
Current maturities of long-term debt	452			50
Accounts payable	672			678
Customer deposits	508			541
Accrued interest and taxes	486			221
Derivatives	67			512
Accrued construction-related expenditures	210			261
Other	384			373
Total current liabilities	3,251			2,966
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,190			1,144
Accumulated deferred income taxes	5,248			4,593
Regulatory liabilities:
Accrued asset removal costs	2,017			2,197
Asset retirement obligation regulatory expense difference	1,814			1,640
Other	361			416
Other	533			527
Total other liabilities and deferred credits	11,163			10,517
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	34,120		$	31,816

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2011 Form 10-K.

11

FLORIDA POWER & LIGHT COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(millions)

(unaudited)

	Nine Months Ended September 30,
	2012			2011
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	984		$	852
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	496			653
Nuclear fuel amortization	74			111
Deferred income taxes	656			439
Cost recovery clauses and franchise fees	115			71
Allowance for equity funds used during construction	(36		)	(26		)
Other - net	51			21
Changes in operating assets and liabilities:
Customer receivables	(305		)	(286		)
Other receivables	16			14
Materials, supplies and fossil fuel inventory	24			(219		)
Other current assets	(35		)	(33		)
Other assets	(41		)	(48		)
Accounts payable	60			69
Customer deposits	(32		)	4
Income taxes	74			(67		)
Interest and other taxes	264			228
Other current liabilities	(55		)	1
Other liabilities	(8		)	(36		)
Net cash provided by operating activities	2,302			1,748
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(3,061		)	(2,128		)
Cash grants under the American Recovery and Reinvestment Act of 2009	—			202
Nuclear fuel purchases	(137		)	(223		)
Proceeds from sale or maturity of securities in special use funds	2,949			2,483
Purchases of securities in special use funds	(3,031		)	(2,534		)
Other - net	27			32
Net cash used in investing activities	(3,253		)	(2,168		)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	594			248
Retirements of long-term debt	(50		)	(45		)
Net change in short-term debt	142			307
Capital contribution from NEE	240			310
Dividends to NEE	—			(400		)
Other - net	9			10
Net cash provided by financing activities	935			430
Net increase (decrease) in cash and cash equivalents	(16		)	10
Cash and cash equivalents at beginning of period	36			20
Cash and cash equivalents at end of period	$	20		$	30
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	$	445		$	420

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2011 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 2011 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.  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						Pension Benefits						Other Benefits
	Three Months Ended September 30,						Three Months Ended September 30,						Nine Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011			2012			2011			2012			2011
	(millions)
Service cost	$	16		$	16		$	1		$	2		$	49		$	48		$	4		$	5
Interest cost	25			25			4			5			74			74			13			16
Expected return on plan assets	(60		)	(60		)	—			(1		)	(179		)	(179		)	(1		)	(2		)
Amortization of transition obligation	—			—			—			1			—			—			1			2
Amortization of prior service cost (benefit)	1			(1		)	(1		)	—			3			(2		)	—			—
Net periodic benefit (income) cost at NEE	$	(18	)	$	(20	)	$	4		$	7		$	(53	)	$	(59	)	$	17		$	21
Net periodic benefit (income) cost at FPL	$	(11	)	$	(13	)	$	3		$	5		$	(34	)	$	(39	)	$	13		$	16

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 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 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 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 energy output of these assets.  These hedges protect NEER against adverse changes in the wholesale forward commodity markets associated with its generation 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 customer served by the distribution utility.  For this type of transaction, derivative instruments are used to hedge the anticipated electricity quantities required to serve these customers and protect against 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.  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) or the capacity cost recovery clause (capacity clause).  For NEE's non-rate regulated operations, predominantly NEER, unless hedge accounting is applied, essentially all changes in the derivatives'

13

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

fair value for power purchases and sales and trading activities are recognized on a net basis in operating revenues; fuel purchases and sales are recognized on a net basis in fuel, purchased power and interchange expense; and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's 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.  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.  Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the condensed consolidated statements of income.  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, 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 swaps 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. At September 30, 2012, NEE's accumulated other comprehensive income (AOCI) included amounts related to discontinued commodity cash flow hedges with expiration dates through December 2012; interest rate cash flow hedges with expiration dates through December 2030; and foreign currency cash flow hedges with expiration dates through September 2030. Approximately $39 million of net losses included in AOCI at September 30, 2012 is expected to be reclassified into earnings within the next 12 months as either the principal and/or interest payments are made or electricity is sold. Such amounts assume no change in power prices, interest rates, currency exchange rates or scheduled principal payments.

In the third quarter of 2011, a subsidiary of NEER entered into an agreement to sell its ownership interest in four natural gas-fired generating plants. See Note 3 - Nonrecurring Fair Value Measurements. Certain of the plants had hedged their exposure to interest rate and commodity price fluctuations by entering into derivative contracts. Because the plants were being sold to a third party, it became no longer probable that the future hedged transactions would occur. Therefore, NEE was required to reclassify any gains or losses in AOCI related to those hedges to earnings. During the three and nine months ended September 30, 2011, NEE reclassified approximately $21 million of net losses to earnings, $30 million of losses were recorded in loss on natural gas-fired generating assets held for sale and $9 million of gains were recorded in other - net.

The net fair values of NEE's and FPL's mark-to-market derivative instrument assets (liabilities) are included on the condensed consolidated balance sheets as follows:

	NEE						FPL
	September 30, 2012			December 31, 2011			September 30, 2012				December 31, 2011
	(millions)
Current derivative assets(a)	$	482		$	611		$	8		(b)	$	10		(b)
Noncurrent derivative assets(c)	944			973			32			(d)	2			(d)
Current derivative liabilities(e)	(486		)	(1,090		)	(67		)		(512		)
Noncurrent derivative liabilities(f)	(530		)	(541		)	—				(1		)	(g)
Total mark-to-market derivative instrument assets (liabilities)	$	410		$	(47	)	$	(27	)		$	(501	)

————————————

(a) At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $40 million and $106 million (none at FPL), respectively, in margin cash collateral received from counterparties.

(b) Included in current other assets on FPL's condensed consolidated balance sheets.

(c) At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $154 million and $109 million (none at FPL), respectively, in margin cash collateral received from counterparties.

(d) Included in noncurrent other assets on FPL's condensed consolidated balance sheets.

(e) At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $74 million and $112 million (none at FPL), respectively, in margin cash collateral provided to counterparties.

(f) At December 31, 2011, NEE's balance reflects the netting of approximately $79 million (none at FPL) in margin cash collateral provided to counterparties.

(g) Included in noncurrent other liabilities on FPL's condensed consolidated balance sheets.

14

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

At September 30, 2012 and December 31, 2011, NEE had approximately $44 million and $22 million (none at FPL), respectively, in margin cash collateral received from counterparties that was not offset against derivative assets.  These amounts are included in current other liabilities on NEE's condensed consolidated balance sheets.  Additionally, at September 30, 2012 and December 31, 2011, NEE had approximately $54 million and $50 million (none at FPL), respectively, in margin cash collateral provided to counterparties that was not offset against derivative liabilities.  These amounts are included in current other assets on NEE's condensed consolidated balance sheets.

As discussed above, NEE uses derivative instruments to, among other things, manage its commodity price risk, interest rate risk and foreign currency exchange rate risk.  The table above presents NEE's and FPL's net derivative positions at September 30, 2012 and December 31, 2011, 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.  However, disclosure rules require that the following tables be presented on a gross basis.

The fair values of NEE's derivatives designated as hedging instruments for accounting purposes (none at FPL) are presented below as gross asset and liability values, as required by disclosure rules.

	September 30, 2012				December 31, 2011
	Derivative Assets		Derivative Liabilities		Derivative Assets		Derivative Liabilities
	(millions)
Interest rate swaps:
Current derivative assets	$	26	$	—	$	22	$	—
Current derivative liabilities	—		97		—		60
Noncurrent derivative assets	54		—		15		—
Noncurrent derivative liabilities	—		294		—		260
Foreign currency swap:
Current derivative liabilities	—		3		—		3
Noncurrent derivative liabilities	—		5		—		3
Total	$	80	$	399	$	37	$	326

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 September 30,
	2012												2011
	Commodity Contracts		Interest Rate Swaps			Foreign Currency Swap				Total			Commodity Contracts		Interest Rate Swaps			Foreign Currency Swaps				Total
	(millions)
Gains (losses) recognized in OCI	$	—	$	(39	)	$	(6	)		$	(45	)	$	—	$	(236	)	$	(14	)		$	(250	)
Gains (losses) reclassified from AOCI to net income(a)	$	2	$	(14	)	$	2		(b)	$	(10	)	$	11	$	(21	)	$	5		(b)	$	(5	)

————————————

(a) Included in operating revenues for commodity contracts and interest expense for interest rate swaps. In 2011, excludes approximately $21 million of net losses related to discontinuance of certain cash flow hedges. See further discussion above.

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

15

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

	Nine Months Ended September 30,
	2012												2011
	Commodity Contracts		Interest Rate Swaps			Foreign Currency Swap				Total			Commodity Contracts		Interest Rate Swaps			Foreign Currency Swaps				Total
	(millions)
Gains (losses) recognized in OCI	$	—	$	(104	)	$	(16	)		$	(120	)	$	—	$	(353	)	$	(20	)		$	(373	)
Gains (losses) reclassified from AOCI to net income(a)	$	6	$	(44	)	$	(4	)	(b)	$	(42	)	$	30	$	(64	)	$	1		(c)	$	(33	)

————————————

(a) Included in operating revenues for commodity contracts and interest expense for interest rate swaps. In 2011, excludes approximately $21 million of net losses related to discontinuance of certain cash flow hedges. See further discussion above.

(b) Loss of approximately $2 million is included in interest expense and the balance is included in other - net.

(c) Loss of approximately $4 million is included in interest expense and the balance is included in other - net.

For the three and nine months ended September 30, 2012, NEE recorded a gain of approximately $6 million and $41 million, respectively, on six fair value hedges which resulted in a corresponding increase in the related debt.  For the three and nine months ended September 30, 2011, NEE recorded a gain of approximately $16 million and $19 million, respectively, on six fair value hedges which resulted in a corresponding increase in the related debt.

The fair values of NEE's and FPL's derivatives not designated as hedging instruments for accounting purposes are presented below as gross asset and liability values, as required by disclosure rules.  However, the majority of the underlying contracts are subject to master netting arrangements and would not be contractually settled on a gross basis.

	September 30, 2012										December 31, 2011
	NEE				FPL						NEE				FPL
	Derivative Assets		Derivative Liabilities		Derivative Assets			Derivative Liabilities			Derivative Assets		Derivative Liabilities		Derivative Assets			Derivative Liabilities
	(millions)
Commodity contracts:
Current derivative assets	$	922	$	426	$	12	(a)	$	4	(a)	$	1,127	$	432	$	11	(a)	$	1	(a)
Current derivative liabilities	1,775		2,233		43			110			3,358		4,494		1			513
Noncurrent derivative assets	1,913		884		32		(b)	—			1,290		250		2		(b)	—
Noncurrent derivative liabilities	233		464		—			—			1,222		1,579		—			1		(c)
Foreign currency swap:
Current derivative liabilities	—		2		—			—			—		3		—			—
Noncurrent derivative assets	15		—		—			—			27		—		—			—
Total	$	4,858	$	4,009	$	87		$	114		$	7,024	$	6,758	$	14		$	515

————————————

(a) Included in current other assets on FPL's condensed consolidated balance sheets.

(b) Included in noncurrent other assets on FPL's condensed consolidated balance sheets.

(c) Included in noncurrent other liabilities on FPL's condensed consolidated balance sheets.

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 (none at FPL) as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(millions)
Commodity contracts(a):
Operating revenues	$	(218	)	$	(50	)	$	102		$	(48	)
Fuel, purchased power and interchange	(4		)	10			36			8
Foreign currency swap - other - net	9			23			(13		)	20
Interest rate contracts - other - net	—			(16		)	—			(11		)
Total	$	(213	)	$	(33	)	$	125		$	(31	)

————————————

(a) For the three months ended September 30, 2012 and 2011, FPL recorded approximately $90 million of gains and $232 million of losses, respectively, related to commodity contracts as regulatory liabilities and regulatory assets, respectively, on its condensed consolidated balance sheets.  For the nine months ended September 30, 2012 and 2011, FPL recorded approximately $86 million and $300 million of losses, respectively, related to commodity contracts as regulatory assets on its condensed consolidated balance sheets.

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.  The table does not present a complete picture of NEE's and FPL's overall net economic exposure because NEE and FPL do not use derivative instruments to hedge all of their commodity exposures.  At September 30, 2012, NEE and FPL had derivative commodity contracts for the following net notional volumes:

Commodity Type	NEE			FPL
	(millions)
Power	(46	)	mwh(a)	—
Natural gas	1,221		mmbtu(b)	837	mmbtu(b)
Oil	(7	)	barrels	—

————————————

(a) Megawatt-hours

(b) One million British thermal units

At September 30, 2012, NEE had interest rate contracts with a notional amount totaling approximately $6.9 billion and foreign currency swaps with a notional amount totaling approximately $544 million.

Certain of NEE's and FPL's 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 September 30, 2012, the aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately $2.2 billion ($115 million for FPL).

If the credit-risk-related contingent features underlying these agreements and other commodity-related contracts were triggered, NEE or 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), NEE would be required to post collateral such that the total posted collateral would be approximately $350 million ($10 million at FPL).If FPL's and NEECH's credit ratings were downgraded to below investment grade, NEE would be required to post additional collateral such that the total posted collateral would be approximately $2.2 billion ($500 million at FPL).  Some contracts at NEE, including some FPL 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, NEE could be required to post additional collateral of up to approximately $600 million ($100 million at FPL).

17

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

Collateral may be posted in the form of cash or credit support.  At September 30, 2012, NEE had posted approximately $210 million (none at FPL) in the form of letters of credit, related to derivatives, in the normal course of business which could be applied toward the collateral requirements described above.  FPL and NEECH have credit facilities 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

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 and FPL primarily hold 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 significant other observable inputs.

NEE and FPL also enter 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.  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, through NEER, also enters into full requirements contracts, which, in many 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.  This consideration includes, but is not limited to, assumptions about market liquidity, volatility and contract duration as more fully described below in Significant Unobservable Inputs.

18

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

NEE uses interest rate and foreign currency swaps to mitigate and adjust interest rate and foreign currency exposure related to certain outstanding and forecasted debt issuances and borrowings.  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 swap 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:

	September 30, 2012
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Netting(a)			Total
	(millions)
Assets:
Cash equivalents:
NEE - equity securities	$	22	$	—		$	—	$	—		$	22
FPL - equity securities	$	1	$	—		$	—	$	—		$	1
Special use funds:
NEE:
Equity securities	$	813	$	1,293	(b)	$	—	$	—		$	2,106
U.S. Government and municipal bonds	$	495	$	169		$	—	$	—		$	664
Corporate debt securities	$	—	$	549		$	—	$	—		$	549
Mortgage-backed securities	$	—	$	594		$	—	$	—		$	594
Other debt securities	$	—	$	47		$	—	$	—		$	47
FPL:
Equity securities	$	150	$	1,142	(b)	$	—	$	—		$	1,292
U.S. Government and municipal bonds	$	442	$	132		$	—	$	—		$	574
Corporate debt securities	$	—	$	381		$	—	$	—		$	381
Mortgage-backed securities	$	—	$	513		$	—	$	—		$	513
Other debt securities	$	—	$	35		$	—	$	—		$	35
Other investments:
NEE:
Equity securities	$	12	$	—		$	—	$	—		$	12
U.S. Government and municipal bonds	$	11	$	—		$	—	$	—		$	11
Corporate debt securities	$	—	$	52		$	—	$	—		$	52
Mortgage-backed securities	$	—	$	47		$	—	$	—		$	47
Other	$	5	$	5		$	—	$	—		$	10
Derivatives:
NEE:
Commodity contracts	$	1,407	$	2,605		$	831	$	(3,512	)	$	1,331	(c)
Interest rate swaps	$	—	$	80		$	—	$	—		$	80	(c)
Foreign currency swaps	$	—	$	15		$	—	$	—		$	15	(c)
FPL - commodity contracts	$	—	$	82		$	5	$	(47	)	$	40	(c)
Liabilities:
Derivatives:
NEE:
Commodity contracts	$	1,461	$	2,197		$	349	$	(3,392	)	$	615	(c)
Interest rate swaps	$	—	$	391		$	—	$	—		$	391	(c)
Foreign currency swaps	$	—	$	10		$	—	$	—		$	10	(c)
FPL - commodity contracts	$	—	$	114		$	—	$	(47	)	$	67	(c)

————————————

(a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and margin cash collateral payments and receipts.

(b) At NEE, approximately $1,217 million ($1,093 million at FPL) are invested in commingled funds whose underlying investments would be Level 1 if those investments were held directly by NEE or FPL.

(c) See Note 2 for a reconciliation of net derivatives to NEE's and FPL's condensed consolidated balance sheets.

19

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

	December 31, 2011
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Netting(a)			Total
	(millions)
Assets:
Cash equivalents:
NEE - equity securities	$	159	$	—		$	—	$	—		$	159
FPL - equity securities	$	11	$	—		$	—	$	—		$	11
Special use funds:
NEE:
Equity securities	$	709	$	1,206	(b)	$	—	$	—		$	1,915
U.S. Government and municipal bonds	$	508	$	167		$	—	$	—		$	675
Corporate debt securities	$	—	$	516		$	—	$	—		$	516
Mortgage-backed securities	$	—	$	511		$	—	$	—		$	511
Other debt securities	$	—	$	47		$	—	$	—		$	47
FPL:
Equity securities	$	128	$	1,056	(b)	$	—	$	—		$	1,184
U.S. Government and municipal bonds	$	458	$	134		$	—	$	—		$	592
Corporate debt securities	$	—	$	359		$	—	$	—		$	359
Mortgage-backed securities	$	—	$	434		$	—	$	—		$	434
Other debt securities	$	—	$	32		$	—	$	—		$	32
Other investments:
NEE:
Equity securities	$	4	$	—		$	—	$	—		$	4
U.S. Government and municipal bonds	$	8	$	—		$	—	$	—		$	8
Corporate debt securities	$	—	$	43		$	—	$	—		$	43
Mortgage-backed securities	$	—	$	33		$	—	$	—		$	33
Other	$	5	$	5		$	—	$	—		$	10
Derivatives:
NEE:
Commodity contracts	$	2,448	$	3,478		$	1,071	$	(5,477	)	$	1,520	(c)
Interest rate swaps	$	—	$	37		$	—	$	—		$	37	(c)
Foreign currency swaps	$	—	$	27		$	—	$	—		$	27	(c)
FPL - commodity contracts	$	—	$	8		$	6	$	(2	)	$	12	(c)
Liabilities:
Derivatives:
NEE:
Commodity contracts	$	2,588	$	3,582		$	585	$	(5,453	)	$	1,302	(c)
Interest rate swaps	$	—	$	320		$	—	$	—		$	320	(c)
Foreign currency swaps	$	—	$	9		$	—	$	—		$	9	(c)
FPL - commodity contracts	$	—	$	513		$	2	$	(2	)	$	513	(c)

————————————

(a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and margin cash collateral payments and receipts.

(b) At NEE, approximately $1,086 million ($979 million at FPL) are invested in commingled funds whose underlying investments would be Level 1 if those investments were held directly by NEE or FPL.

(c) See Note 2 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)

Significant Unobservable Inputs - 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 Risk Management group.  The Risk Management group performs a risk management function within NEE and FPL 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 Risk Management group is separate from the transacting group, and the Vice President of Risk Management reports to the Chief Financial Officer of NEE and FPL.  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 Vice President of Risk Management.  In addition, other valuation assumptions such as implied correlations and customer migration rates are reviewed and approved by Risk Management on a periodic basis.  Newly created models used in the valuation process are also subject to testing and approval by Risk Management prior to use and established models are reviewed annually, or more often as needed, by Risk Management.

On a monthly basis, the Exposure Management Committee (EMC), which is comprised of certain members of senior management, meets with representatives from the 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 Risk Management policy.  The EMC executes its risk management responsibilities through direct oversight and delegation of its responsibilities to the Vice President of Risk Management, as well as to other corporate and business unit personnel.

The significant unobservable inputs used in the valuation of contracts categorized as Level 3 of the fair value hierarchy at September 30, 2012 are as follows:

Transaction Type	Fair Value at September 30, 2012		Valuation Technique(s)	Significant Unobservable Inputs	Range
	Assets	Liabilities
	(millions)
Forward contracts - power	$366	$95	Discounted cash flow	Forward price (per mwh)	$10	–	$141
Options - power	$179	$200	Option models	Implied correlations	12%	—	98%
				Implied volatilities	1%	—	154%
Options - gas	$43	$10	Option models	Implied correlations	12%	—	98%
				Implied volatilities	1%	—	56%
Full requirements and unit contingent contracts	$211	$33	Discounted cash flow	Forward price (per mwh)	$5	—	$127
				Customer migration rate(a)	—%	—	20%

——————————

(a) Applies only to full requirements contracts.

21

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	Increase (decrease)
	Sell power	Decrease (increase)
Implied correlations	Purchase option	Decrease (increase)
	Sell option	Increase (decrease)
Implied volatilities	Purchase option	Increase (decrease)
	Sell option	Decrease (increase)
Customer migration rate	Sell power(a)	Decrease (increase)

————————————

(a) Assumes the contract is in a gain position.

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

	Three Months Ended September 30,
	2012						2011
	NEE			FPL			NEE			FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at June 30	$	575		$	7		$	155		$	5
Realized and unrealized gains (losses):
Included in earnings(a)	(149		)	—			(11		)	—
Included in regulatory assets and liabilities	1			1			—			—
Purchases	40			—			45			—
Settlements	30			(3		)	3			(1		)
Issuances	(21		)	—			(70		)	—
Transfers in(b)	5			—			1			—
Transfers out(b)	1			—			(2		)	—
Fair value of net derivatives based on significant unobservable inputs at September 30	$	482		$	5		$	121		$	4
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)	$	(171	)	$	—		$	12		$	—

————————————

(a) For the three months ended September 30, 2012 and 2011, $(149) million and $(12) million, respectively, of realized and unrealized gains (losses) are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

(b) For the three months ended September 30, 2012 and 2011, 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 September 30, 2012 and 2011, $(170) million and $12 million, respectively, of unrealized gains (losses) are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

22

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

	Nine Months Ended September 30,
	2012						2011
	NEE			FPL			NEE			FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year	$	486		$	4		$	296		$	7
Realized and unrealized gains (losses):
Included in earnings(a)	135			—			2			—
Included in regulatory assets and liabilities	7			7			2			2
Purchases	221			—			186			—
Settlements	(152		)	(6		)	(100		)	(5		)
Issuances	(221		)	—			(260		)	—
Transfers in(b)	21			—			3			—
Transfers out(b)	(15		)	—			(8		)	—
Fair value of net derivatives based on significant unobservable inputs at September 30	$	482		$	5		$	121		$	4
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)	$	41		$	—		$	42		$	—

————————————

(a) For the nine months ended September 30, 2012 and 2011, $132 million and $(11) million, respectively, of realized and unrealized gains (losses) are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

(b) For the nine months ended September 30, 2012 and 2011, 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 nine months ended September 30, 2012 and 2011, $41 million and $37 million, respectively, of unrealized gains (losses) 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 the second quarter of 2011, market value indications and the potential impact of proposed environmental regulations suggested that the carrying value of certain NEER assets, primarily wind assets in West Texas and oil-fired assets in Maine, could be impaired.  NEER performed a fair value analysis and concluded that an impairment charge related to the long-lived assets, primarily property, plant and equipment, was necessary.  The fair value analysis was primarily based on the income approach using significant unobservable inputs (Level 3) including revenue and generation forecasts, projected capital and maintenance expenditures and discount rates.  As a result, long-lived assets held and used with a carrying amount of approximately $79 million were written down to their fair value of $28 million, resulting in an impairment charge of $51 million ($31 million after-tax), which is recorded as a separate line item in NEE’s condensed consolidated statements of income for the nine months ended September 30, 2011.

In the third quarter of 2011, a subsidiary of NEER entered into an agreement to sell its ownership interest in four natural gas-fired generating plants with a total generating capacity of 2,152 mw. In connection with the agreement to sell, during the three and nine months ended September 30, 2011, a loss of approximately $148 million ($97 million after-tax) was recorded in NEE's condensed consolidated statements of income consisting of the impact of writing down the net natural gas-fired generating assets held for sale to their estimated fair value less costs to sell and the reclassification of $30 million from AOCI as a result of the discontinuance of certain cash flow hedges because it became no longer probable that the future hedged transactions would occur. See Note 2. The sale of the four natural gas-fired plants discussed above and the sale of one additional natural gas-fired plant were completed in the fourth quarter of 2011.

23

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

4.  Financial Instruments

The carrying amounts of cash equivalents and commercial paper approximate their fair values.  At September 30, 2012 and December 31, 2011, other investments of NEE, not included in the table below, included financial instruments of approximately $41 million and $35 million ($8 million and $4 million at FPL), respectively, which primarily consist of notes receivable that are carried at estimated fair value or cost, which approximates fair value.

The following estimates of the fair value of financial instruments have been made primarily using available market information.  However, the use of different market assumptions or methods of valuation could result in different estimated fair values.

	September 30, 2012								December 31, 2011
	Carrying Amount				Estimated Fair Value				Carrying Amount				Estimated Fair Value
	(millions)
NEE:
Special use funds	$	4,223		(a)	$	4,223		(a)	$	3,867		(a)	$	3,867		(a)
Other investments:
Notes receivable	$	500			$	681		(b)	$	503			$	535		(b)
Debt securities	$	115		(c)	$	115		(d)	$	89		(c)	$	89		(d)
Equity securities	$	61			$	75		(e)	$	80			$	159		(e)
Long-term debt, including current maturities	$	24,769			$	27,674		(f)	$	21,614			$	23,699		(f)
Interest rate swaps - net unrealized losses	$	(311	)		$	(311	)	(d)	$	(283	)		$	(283	)	(d)
Foreign currency swaps - net unrealized gains	$	5			$	5		(d)	$	18			$	18		(d)
FPL:
Special use funds	$	2,967		(a)	$	2,967		(a)	$	2,737		(a)	$	2,737		(a)
Long-term debt, including current maturities	$	8,084			$	9,984		(f)	$	7,533			$	9,078		(f)

————————————

(a) At September 30, 2012, includes $229 million of investments accounted for under the equity method and $34 million of loans not measured at fair value on a recurring basis ($144 million and $28 million, respectively, for FPL).  At December 31, 2011, includes $164 million of investments accounted for under the equity method and $39 million of loans not measured at fair value on a recurring basis ($112 million and $24 million, respectively, for FPL).  For the remaining balances, see Note 3 for classification by major security type and hierarchy level.  The amortized cost of debt and equity securities is $1,753 million and $1,437 million, respectively, at September 30, 2012 and $1,638 million and $1,425 million, respectively, at December 31, 2011 ($1,417 million and $791 million, respectively, at September 30, 2012 and $1,321 million and $864 million, respectively, at December 31, 2011 for FPL).

(b) Classified as held to maturity.  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 standings and ratings and market-related information.  As of September 30, 2012, NEE had no notes receivable reported in non-accrual status.

(c) Classified as trading securities.

(d) See Note 3.

(e) Primarily modeled internally based on recent market information including, among other things, private offerings of the securities (Level 3).

(f) As of September 30, 2012 and December 31, 2011, $15,873 million and $15,035 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 consist of FPL's storm fund assets of $127 million and NEE's and FPL's nuclear decommissioning fund assets of $4,096 million and $2,840 million, respectively, at September 30, 2012.  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 (see Note 3).  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 September 30, 2012 of approximately six years at both NEE and FPL.  FPL's storm fund primarily consists of debt securities with a weighted-average maturity at September 30, 2012 of approximately three years.  The cost of securities sold is determined using the specific identification method.

24

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

Realized gains and losses and proceeds from the sale or maturity of available for sale securities are as follows:

	NEE				FPL				NEE				FPL
	Three Months Ended September 30,				Three Months Ended September 30,				Nine Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011		2012		2011		2012		2011
	(millions)
Realized gains	$	75	$	69	$	20	$	22	$	206	$	156	$	81	$	60
Realized losses	$	16	$	27	$	12	$	17	$	48	$	70	$	34	$	51
Proceeds from sale or maturity of securities	$	953	$	992	$	592	$	675	$	3,890	$	3,567	$	2,949	$	2,483

Unrealized losses on available for sale debt securities at September 30, 2012 and December 31, 2011 were not material to NEE or FPL.  The unrealized gains on available for sale securities are as follows:

	NEE				FPL
	September 30, 2012		December 31, 2011		September 30, 2012		December 31, 2011
	(millions)
Equity securities	$	694	$	546	$	526	$	376
U.S. Government and municipal bonds	$	32	$	46	$	29	$	43
Corporate debt securities	$	43	$	31	$	32	$	24
Mortgage-backed securities	$	25	$	27	$	22	$	24
Other debt securities	$	2	$	3	$	2	$	3

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.

Interest Rate and Foreign Currency Swaps - NEE and its subsidiaries use a combination of fixed rate and variable rate debt to manage interest rate exposure.  Interest rate swaps are used to mitigate and adjust interest rate exposure when deemed appropriate based upon market conditions or when required by financing agreements.  In addition, with respect to certain debt issuances and borrowings, NEECH has two cross currency swaps to hedge against currency movements with respect to both interest and principal payments.  See Note 2.

5.  Income Taxes

NEE's effective income tax rates for the three months ended September 30, 2012 and 2011 were approximately 27% and 28%, respectively.  The reduction from the federal statutory rate for those respective periods mainly reflects the benefit of wind production tax credits (PTCs) of approximately $35 million and $45 million related to NEER's wind projects and approximately $14 million and $9 million of 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), primarily for certain wind projects expected to be placed in service.

25

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

NEE's effective income tax rates for the nine months ended September 30, 2012 and 2011 were approximately 27% and 18%, respectively.  The reduction from the federal statutory rate for those respective periods mainly reflects the benefit of wind PTCs of approximately $147 million and $208 million and approximately $37 million and $17 million of deferred income tax benefits associated with convertible ITCs. NEE's effective income tax rate for the nine months ended September 30, 2011 also reflects a state deferred income tax benefit included in the Corporate and Other segment of approximately $64 million, net of federal income taxes, related to state tax law changes in 2011 (state deferred income tax benefit) and a $26 million reduction in income tax expense, net of federal income taxes, primarily related to a valuation allowance reversal for certain state ITCs reflecting state income tax planning initiatives (state ITC benefit).

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 expiration of PTCs after ten years of production.

6.  Variable Interest Entities (VIEs)

As of September 30, 2012, NEE has ten 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 $356 million and $406 million at September 30, 2012 and December 31, 2011, 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 $441 million and $496 million at September 30, 2012 and December 31, 2011, 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 (PPA) effective in 1994 with this 250 megawatt (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 PPA 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 passed on to FPL's customers 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 September 30, 2012 and 2011, FPL purchased 293,650 mwh and 327,583 mwh, respectively, from the facility at a total cost of approximately $48 million and $50 million, respectively. During the nine months ended September 30, 2012 and 2011, FPL purchased 582,661 mwh and 965,105 mwh, respectively, from the facility at a total cost of approximately $133 million and $144 million, respectively.

26

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

Additionally, FPL entered into a PPA 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 passed on to FPL’s customers through the fuel clause as approved by the FPSC.

NEER - NEE consolidates nine 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.

An 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. The assets and liabilities of the VIE were approximately $96 million and $74 million, respectively, at September 30, 2012 and $105 million and $82 million, respectively, at December 31, 2011, and consisted primarily of property, plant and equipment and long-term debt.

The other eight NEER VIEs consolidate several entities which own and operate wind electric generating facilities with the capability of producing a total of 2,658 mw.  Seven of these VIEs sell their electric output under power sales contracts to third parties with expiration dates ranging from 2018 through 2037; the eighth VIE sells its 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.  The debt holders have no recourse to the general credit of NEER.  The assets and liabilities of these VIEs totaled approximately $4.1 billion and $2.8 billion, respectively, at September 30, 2012. Six of the eight were VIEs at December 31, 2011 and were consolidated; the assets and liabilities of those VIEs totaled approximately $3.2 billion and $2.6 billion, respectively, at December 31, 2011. At September 30, 2012 and December 31, 2011, 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 September 30, 2012 and December 31, 2011, several NEE subsidiaries have investments totaling approximately $784 million ($619 million at FPL) and $668 million ($526 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 September 30, 2012, 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.

27

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

7.  Common Stock

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
	(millions, except per share amounts)
Numerator - net income	$	415	$	407	$	1,482	$	1,256
Denominator:
Weighted-average number of common shares outstanding - basic	419.3		417.4		415.6		416.7
Performance share awards, options, restricted stock and equity units(a)	2.4		2.4		2.4		2.4
Weighted-average number of common shares outstanding - assuming dilution	421.7		419.8		418.0		419.1
Earnings per share of common stock:
Basic	$	0.99	$	0.98	$	3.57	$	3.01
Assuming dilution	$	0.98	$	0.97	$	3.55	$	3.00

————————————

(a) 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.  Performance share awards, options, restricted stock and equity units are included in diluted weighted-average number of common shares outstanding by applying the treasury stock method.

Common shares issuable pursuant to equity units and stock options, performance shares and restricted stock awards which were not included in the denominator above due to their antidilutive effect were approximately 3.2 million and 14.6 million for the three months ended September 30, 2012 and 2011, respectively, and 9.9 million and 14.5 million for the nine months ended September 30, 2012 and 2011, respectively.

8.  Debt

Long-term debt issuances and borrowings by subsidiaries of NEE during the nine months ended September 30, 2012 were as follows:

Date Issued	Company	Debt Issuances/Borrowings	Interest Rate			Principal Amount		Maturity Date
						(millions)
January - September 2012	NEECH and NEER subsidiary	Canadian revolving credit facilities	Variable		(a)	$	146	2013
January - September 2012	NEER subsidiaries	Euro denominated senior secured limited-recourse loan	Variable		(a)(b)	$	247	2030
January - September 2012	NEER subsidiaries	Euro denominated senior secured limited-recourse loan	Variable		(a)	$	48	2015
January - September 2012	NEECH and NEER subsidiary	Euro denominated revolving loan	Variable		(a)	$	81	2014
January - August 2012	Lone Star Transmission, LLC	Senior secured limited-recourse loan	Variable		(a)	$	150	2016
March 2012	NEECH	Junior subordinated debentures	5.70	%		$	400	2072
May 2012	NEECH	Debentures related to NEE's equity units	1.70	%		$	600	2017
May 2012	FPL	First mortgage bonds	4.05	%		$	600	2042
June 2012	NEECH	Junior subordinated debentures	5.625	%		$	350	2072
July 2012	NEER subsidiary	Limited-recourse term loan	Variable		(a)(b)	$	99	2015
September 2012	NEECH	Debentures related to NEE's equity units	1.60	%		$	650	2017
September 2012	NEECH	Debentures	1.20	%		$	500	2015
September 2012	NEER subsidiary	Canadian senior secured limited-recourse notes	4.881	%		$	176	2031
September 2012	NEER subsidiary	Senior secured limited-recourse loan	Variable		(a)(b)	$	232	2030

————————————

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

(b) Interest rate swap agreements were entered into with respect to these issuances.

28

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

In May 2012, NEE sold $600 million of equity units (initially consisting of Corporate Units).  Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series E Debenture due June 1, 2017 issued in the principal amount of $1,000 by NEECH (see table above).  Each stock purchase contract requires the holder to purchase by no later than June 1, 2015 (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range of $64.35 to $77.22.  If purchased on the final settlement date, as of September 30, 2012, the number of shares issued would (subject to antidilution adjustments) range from 0.7770 shares if the applicable market value of a share of common stock is less than or equal to $64.35, to 0.6475 shares if the applicable market value of a share is equal to or greater than $77.22, with applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending May 27, 2015.  Total annual distributions on the equity units will be at the rate of 5.599%, consisting of interest on the debentures (1.70% per year) and payments under the stock purchase contracts (3.899% per year).  The interest rate on the debentures is expected to be reset on or after December 1, 2014.  The holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit.  The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder’s obligation to purchase NEE common stock under the related stock purchase contract.  If a successful remarketing does not occur on or before the third business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE.

Also, in May 2012, a remarketing of $350 million aggregate principal amount of Series C Debentures due June 1, 2014 (Debentures) issued by NEECH was successfully completed.  The Debentures were originally issued in May 2009 as components of NEE's equity units (2009 equity units).  The Debentures are fully and unconditionally guaranteed by NEE.  In connection with the remarketing of the Debentures, the annual interest rate on the Debentures was reset to 1.611% and interest is payable semi-annually on June 1 and December 1, beginning June 1, 2012. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the 2009 equity units, on June 1, 2012, NEE issued 5,400,500 shares of common stock in exchange for $350 million.

In September 2012, NEE sold $650 million of equity units (initially consisting of Corporate Units).  Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series F Debenture due September 1, 2017 issued in the principal amount of $1,000 by NEECH (see table above).  Each stock purchase contract requires the holder to purchase by no later than September 1, 2015 (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range of $67.15 to $80.58.  If purchased on the final settlement date, as of September 30, 2012, the number of shares issued would (subject to antidilution adjustments) range from 0.7446 shares if the applicable market value of a share of common stock is less than or equal to $67.15, to 0.6205 shares if the applicable market value of a share is equal to or greater than $80.58, with applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending August 27, 2015.  Total annual distributions on the equity units will be at the rate of 5.889%, consisting of interest on the debentures (1.60% per year) and payments under the stock purchase contracts (4.289% per year).  The interest rate on the debentures is expected to be reset on or after March 1, 2015.  The holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit.  The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder’s obligation to purchase NEE common stock under the related stock purchase contract.  If a successful remarketing does not occur on or before the third business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE.

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 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 transmission line and other associated facilities by Lone Star Transmission, LLC (Lone Star), a rate-regulated transmission service provider in Texas, and the cost to meet customer-specific requirements and maintain the fiber-optic network for the fiber-optic telecommunications business (FPL FiberNet).

29

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

At September 30, 2012, estimated capital expenditures for the remainder of 2012 through 2016 were as follows:

	Remainder of 2012		2013		2014		2015		2016		Total
	(millions)
FPL:
Generation:(a)
New(b)(c)	$	500	$	770	$	770	$	295	$	120	$	2,455
Existing	190		645		655		550		440		2,480
Transmission and distribution	215		690		690		660		705		2,960
Nuclear fuel	70		125		205		245		245		890
General and other	45		190		120		80		85		520
Total	$	1,020	$	2,420	$	2,440	$	1,830	$	1,595	$	9,305
NEER:
Wind(d)	$	740	$	285	$	25	$	5	$	5	$	1,060
Solar(e)	390		670		160		5		—		1,225
Nuclear(f)	95		315		280		285		325		1,300
Other(g)	85		200		120		135		60		600
Total	$	1,310	$	1,470	$	585	$	430	$	390	$	4,185
Corporate and Other(h)	$	115	$	115	$	45	$	45	$	45	$	365

————————————

(a) Includes allowance for funds used during construction (AFUDC) of approximately $24 million, $82 million, $53 million, $48 million and $27 million in 2012 to 2016, respectively.

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

(c) Consists of projects that have received FPSC approval.  Includes pre-construction costs and carrying charges (equal to a pretax AFUDC rate) on construction costs recoverable through the capacity clause of approximately $24 million, $42 million and $12 million in 2012 to 2014, respectively.  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) Consists of capital expenditures for planned new wind projects and related transmission totaling approximately 1,500 mw, including approximately 150 mw in Canada, that have received applicable internal approvals.  Excludes new Canadian wind projects requiring internal approvals with generation totaling approximately 470 mw in 2014 and 2015, with an estimated cost of approximately $1.3 billion to $1.5 billion.

(e) Consists of capital expenditures for planned new solar projects and related transmission totaling 625 mw that have received applicable internal approvals, including equity contributions associated with a 50% equity method investment in a 550 mw solar project.  Excludes solar projects requiring internal approvals with generation totaling 270 mw with an estimated cost of approximately $600 million to $800 million.

(f) Includes nuclear fuel.

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

(h) Consists of capital expenditures that have received applicable internal approvals and includes AFUDC of approximately $9 million and $14 million in 2012 and 2013, respectively.

These estimates are subject to continuing review and adjustment and actual capital expenditures may vary significantly from these estimates.

Contracts - In addition to the estimated capital expenditures included in the table in Commitments above, FPL has commitments under long-term purchased power and fuel contracts.  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.

NEER has entered into contracts primarily for the purchase of wind turbines and towers, solar reflectors, steam turbine generators and heat collection elements and related construction and development activities, as well as for the supply of uranium, conversion, enrichment and fabrication of nuclear fuel, with expiration dates ranging from December 2012 through 2030, approximately $1.7 billion of which is 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 December 2012 through 2033.

30

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

The transmission business included in Corporate and Other has entered into contracts primarily for development and construction activities relating to Lone Star's transmission line and other associated facilities, all of which is included in the estimated capital expenditures table in Commitments above.

The required capacity and/or minimum payments under the contracts discussed above as of September 30, 2012 were estimated as follows:

	Remainder of 2012		2013		2014		2015		2016		Thereafter
	(millions)
FPL:
Capacity charges:(a)
Qualifying facilities	$	75	$	270	$	275	$	280	$	245	$	2,415
JEA and Southern subsidiaries	$	60	$	230	$	220	$	195	$	70	$	155
Minimum charges, at projected prices:
Natural gas, including transportation and storage(b)	$	495	$	1,580	$	1,065	$	570	$	535	$	6,935
Coal(b)	$	25	$	90	$	35	$	5	$	5	$	—
NEER	$	610	$	690	$	235	$	85	$	105	$	600
Corporate and Other(c)	$	65	$	30	$	10	$	15	$	15	$	20

————————————

(a) Capacity charges under these contracts, substantially all of which are recoverable through the capacity clause, totaled approximately $129 million and $128 million for the three months ended September 30, 2012 and 2011, respectively, and approximately $391 million and $383 million for the nine months ended September 30, 2012 and 2011, respectively. Energy charges under these contracts, which are recoverable through the fuel clause, totaled approximately $110 million and $135 million for the three months ended September 30, 2012 and 2011, respectively, and approximately $232 million and $348 million for the nine months ended September 30, 2012 and 2011, respectively.

(b) Recoverable through the fuel clause.

(c) Includes an approximately $68 million commitment to invest in clean power and technology businesses through 2017.

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 $12.2 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 $940 million ($470 million for FPL), plus any applicable taxes, per incident at any nuclear reactor in the United States, payable at a rate not to exceed $140 million ($70 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 $14 million, $35 million and $18 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.  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 $178 million ($102 million for FPL), plus any applicable taxes, in retrospective premiums in a policy year.  NEE and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook, Duane Arnold and St. Lucie Unit No. 2, which approximates $2 million, $4 million and $4 million, plus any applicable taxes, respectively.

Due to the high cost and limited coverage available from third-party insurers, NEE does not have insurance coverage for a substantial portion of its transmission and distribution property and has no 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, would be borne by NEE and FPL and could have a material adverse effect on NEE's and FPL's financial condition, results of operations and liquidity.

31

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

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 a 76% interest, 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 October 2004, TXU Portfolio Management Company (TXU) served FPL Energy Pecos Wind I, LP, FPL Energy Pecos Wind I GP, LLC, FPL Energy Pecos Wind II, LP, FPL Energy Pecos Wind II GP, LLC and Indian Mesa Wind Farm, LP (NEER Affiliates) as defendants in a civil action filed in the District Court in Dallas County, Texas.  FPL Energy, LLC, now known as NextEra Energy Resources, LLC, was added as a defendant in 2005.  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.  The plaintiff 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, among other findings, both TXU and the NEER Affiliates were found to have breached the contracts.  In August 2008, the trial court issued a final judgment holding that the contracts were not terminated and neither party was entitled to recover any damages.  In November 2008, TXU appealed the final judgment to the Fifth District Court of Appeals in Dallas, Texas.  In an opinion issued in July 2010, the appellate court reversed portions of the trial court's judgment, ruling that the contracts' liquidated damage provision is an enforceable liquidated damage clause.  The appellate court ordered that the case be remanded back to the trial court for further proceedings to determine the amount of damages payable by the NEER Affiliates.  The NEER Affiliates filed a motion for rehearing of the appellate court’s decision, which motion was denied, and in April 2011 filed a petition for review of the appellate court decision with the Texas Supreme Court.  In February 2012, the Texas Supreme Court granted the petition for review and oral arguments were heard in October 2012.

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 NEE or FPL has an ownership interest are also involved in legal and regulatory proceedings, actions and claims, the liabilities from which, if any, would be shared by NEE or FPL.  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.

32

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

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 September 30,
	2012										2011
	FPL		NEER(a)			Corporate and Other			NEE Consoli- dated		FPL		NEER(a)			Corporate and Other				NEE Consoli- dated
									(millions)
Operating revenues	$	2,975	$	808		$	60		$	3,843	$	3,152	$	1,172		$	58			$	4,382
Operating expenses	$	2,256	$	785		$	53		$	3,094	$	2,496	$	920		$	55			$	3,471
Net income	$	392	$	44	(b)	$	(21	)	$	415	$	347	$	67	(b)	$	(7	)	(c)	$	407

	Nine Months Ended September 30,
	2012										2011
	FPL		NEER(a)			Corporate and Other			NEE Consoli- dated		FPL		NEER(a)			Corporate and Other			NEE Consoli- dated
									(millions)
Operating revenues	$	7,778	$	2,929		$	174		$	10,881	$	8,200	$	3,110		$	166		$	11,476
Operating expenses	$	5,916	$	2,201		$	149		$	8,266	$	6,566	$	2,520	(d)	$	144		$	9,230
Net income	$	984	$	516	(b)	$	(18	)	$	1,482	$	852	$	371	(b)(e)	$	33	(c)(f)	$	1,256

	September 30, 2012								December 31, 2011
	FPL		NEER		Corporate and Other		NEE Consoli- dated		FPL		NEER		Corporate and Other		NEE Consoli- dated
							(millions)
Total assets	$	34,120	$	25,761	$	2,168	$	62,049	$	31,816	$	23,459	$	1,913	$	57,188

————————————

(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) See Note 5 for a discussion of NEER's tax benefits related to PTCs. 2011 includes after-tax loss on natural gas-fired generating assets held for sale of $91 million.  See Note 3 - Nonrecurring Fair Value Measurements.  

(c) Includes after-tax loss on natural gas-fired generating assets held for sale of $6 million.  See Note 3 - Nonrecurring Fair Value Measurements.

(d) Includes impairment charges of approximately $51 million.  See Note 3 - Nonrecurring Fair Value Measurements.

(e) Includes after-tax impairment charges of approximately $31 million.  See Note 3 - Nonrecurring Fair Value Measurements.

(f) Includes the state deferred income tax benefit of approximately $64 million.  See Note 5.

33

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

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 September 30,
	2012												2011
	NEE (Guarantor)			NEECH			Other(a)			NEE Consoli- dated			NEE (Guarantor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
Operating revenues	$	—		$	871		$	2,972		$	3,843		$	—		$	1,232		$	3,150		$	4,382
Operating expenses	(5		)	(836		)	(2,253		)	(3,094		)	(4		)	(973		)	(2,494		)	(3,471		)
Interest expense	(2		)	(155		)	(102		)	(259		)	(3		)	(164		)	(98		)	(265		)
Equity in earnings of subsidiaries	416			—			(416		)	—			416			—			(416		)	—
Other income (deductions) - net	4			61			14			79			1			(86		)	4			(81		)
Income (loss) before income taxes	413			(59		)	215			569			410			9			146			565
Income tax expense (benefit)	(2		)	(82		)	238			154			3			(60		)	215			158
Net income (loss)	$	415		$	23		$	(23	)	$	415		$	407		$	69		$	(69	)	$	407

	Nine Months Ended September 30,
	2012												2011
	NEE(Guarantor)			NEECH			Other(a)			NEE Consoli- dated			NEE(Guarantor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
Operating revenues	$	—		$	3,112		$	7,769		$	10,881		$	—		$	3,285		$	8,191		$	11,476
Operating expenses	(13		)	(2,346		)	(5,907		)	(8,266		)	(11		)	(2,662		)	(6,557		)	(9,230		)
Interest expense	(8		)	(479		)	(308		)	(795		)	(10		)	(486		)	(279		)	(775		)
Equity in earnings of subsidiaries	1,480			—			(1,480		)	—			1,214			—			(1,214		)	—
Other income (deductions) - net	5			180			30			215			1			40			17			58
Income (loss) before income taxes	1,464			467			104			2,035			1,194			177			158			1,529
Income tax expense (benefit)	(18		)	(29		)	600			553			(62		)	(185		)	520			273
Net income (loss)	$	1,482		$	496		$	(496	)	$	1,482		$	1,256		$	362		$	(362	)	$	1,256

————————————

(a)  Represents FPL and consolidating adjustments.

Condensed Consolidating Statements of Comprehensive Income

	Three Months Ended September 30,
	2012									2011
	NEE (Guarantor)		NEECH			Other(a)		NEE Consoli- dated		NEE (Guarantor)		NEECH			Other(a)		NEE Consoli- dated
								(millions)
Comprehensive income (loss)	$	386	$	(6	)	$	6	$	386	$	178	$	(160	)	$	160	$	178

	Nine Months Ended September 30,
	2012									2011
	NEE (Guarantor)		NEECH		Other(a)			NEE Consoli- dated		NEE (Guarantor)		NEECH		Other(a)			NEE Consoli- dated
								(millions)
Comprehensive income (loss)	$	1,417	$	437	$	(437	)	$	1,417	$	976	$	76	$	(76	)	$	976

————————————

(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

	September 30, 2012												December 31, 2011
	NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated			NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
PROPERTY, PLANT AND EQUIPMENT
Electric utility plant in service and other property	$	31		$	25,778		$	37,621		$	63,430		$	31		$	22,351		$	35,170		$	57,552
Less accumulated depreciation and amortization	(6		)	(4,817		)	(10,914		)	(15,737		)	(3		)	(4,143		)	(10,916		)	(15,062		)
Total property, plant and equipment - net	25			20,961			26,707			47,693			28			18,208			24,254			42,490
CURRENT ASSETS
Cash and cash equivalents	1			226			19			246			1			339			37			377
Receivables	112			1,090			920			2,122			84			1,026			692			1,802
Other	5			1,003			1,061			2,069			5			1,075			1,613			2,693
Total current assets	118			2,319			2,000			4,437			90			2,440			2,342			4,872
OTHER ASSETS
Investment in subsidiaries	15,858			—			(15,858		)	—			14,879			—			(14,879		)	—
Other	745			4,783			4,391			9,919			513			4,849			4,464			9,826
Total other assets	16,603			4,783			(11,467		)	9,919			15,392			4,849			(10,415		)	9,826
TOTAL ASSETS	$	16,746		$	28,063		$	17,240		$	62,049		$	15,510		$	25,497		$	16,181		$	57,188
CAPITALIZATION
Common shareholders' equity	$	15,886		$	3,784		$	(3,784	)	$	15,886		$	14,943		$	4,030		$	(4,030	)	$	14,943
Long-term debt	—			15,082			7,632			22,714			—			13,327			7,483			20,810
Total capitalization	15,886			18,866			3,848			38,600			14,943			17,357			3,453			35,753
CURRENT LIABILITIES
Debt due within one year	—			2,712			924			3,636			—			1,778			379			2,157
Accounts payable	—			522			672			1,194			—			512			679			1,191
Other	289			1,410			1,346			3,045			250			1,520			1,601			3,371
Total current liabilities	289			4,644			2,942			7,875			250			3,810			2,659			6,719
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	—			495			1,190			1,685			—			466			1,145			1,611
Accumulated deferred income taxes	67			1,273			4,826			6,166			68			1,376			4,237			5,681
Other	504			2,785			4,434			7,723			249			2,488			4,687			7,424
Total other liabilities and deferred credits	571			4,553			10,450			15,574			317			4,330			10,069			14,716
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	16,746		$	28,063		$	17,240		$	62,049		$	15,510		$	25,497		$	16,181		$	57,188

————————————

(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

	Nine Months Ended September 30,
	2012												2011
	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	$	662		$	878		$	1,617		$	3,157		$	979		$	1,071		$	1,067		$	3,117
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	—			(3,492		)	(3,197		)	(6,689		)	(16		)	(1,950		)	(2,351		)	(4,317		)
Capital contribution to FPL	(240		)	—			240			—			(310		)	—			310			—
Cash grants under the Recovery Act	—			105			—			105			—			301			202			503
Change in loan proceeds restricted for construction	—			212			—			212			—			(596		)	—			(596		)
Other - net	—			(59		)	(70		)	(129		)	16			4			(32		)	(12		)
Net cash used in investing activities	(240		)	(3,234		)	(3,027		)	(6,501		)	(310		)	(2,241		)	(1,871		)	(4,422		)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	—			3,632			594			4,226			—			2,669			248			2,917
Retirements of long-term debt	—			(1,272		)	(49		)	(1,321		)	—			(1,643		)	(45		)	(1,688		)
Proceeds from sale of differential membership interests	—			414			—			414			—			210			—			210
Net change in short-term debt	—			254			142			396			—			639			307			946
Issuances of common stock	386			—			—			386			39			—			—			39
Dividends on common stock	(752		)	—			—			(752		)	(689		)	—			—			(689		)
Other - net	(56		)	(785		)	705			(136		)	(19		)	(377		)	304			(92		)
Net cash provided by (used in) financing activities	(422		)	2,243			1,392			3,213			(669		)	1,498			814			1,643
Net increase (decrease) in cash and cash equivalents	—			(113		)	(18		)	(131		)	—			328			10			338
Cash and cash equivalents at beginning of period	1			339			37			377			—			282			20			302
Cash and cash equivalents at end of period	$	1		$	226		$	19		$	246		$	—		$	610		$	30		$	640

————————————

(a) Represents FPL and consolidating adjustments.

36

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

This discussion should be read in conjunction with the Notes contained herein and Management's Discussion and Analysis of Financial Condition and Results of Operations (Management's Discussion) appearing in the 2011 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 discussion, all comparisons are with the corresponding items in the prior year period.

OVERVIEW

NEE’s operating performance is driven primarily by the operations of its two principal subsidiaries, FPL, which serves approximately 4.6 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 the U.S. of renewable energy from the wind and sun.  The table below presents NEE’s net income and earnings per share by reportable segment - FPL, NEER and Corporate and Other, which is primarily comprised of interest expense, the operating results of FPL FiberNet, Lone Star and other business activities, as well as other income and expense items, including income taxes and eliminating entries (see Note 10 for additional segment information).

	Net Income						Earnings Per Share, assuming dilution						Net Income					Earnings Per Share, assuming dilution
	Three Months Ended September 30,												Nine Months Ended September 30,
	2012			2011			2012			2011			2012			2011		2012			2011
	(millions, except per share amounts)
FPL	$	392		$	347		$	0.93		$	0.83		$	984		$	852	$	2.35		$	2.03
NEER(a)	44			67			0.10			0.16			516			371		1.23			0.89
Corporate and Other	(21		)	(7		)	(0.05		)	(0.02		)	(18		)	33		(0.03		)	0.08
NEE	$	415		$	407		$	0.98		$	0.97		$	1,482		$	1,256	$	3.55		$	3.00

____________________

(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 in accordance with U.S. generally accepted accounting principles (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 whether performance goals are met for 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 in accordance with 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 in accordance with GAAP.

Adjusted earnings exclude the unrealized mark-to-market effect of non-qualifying hedges (as described below), 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) and, for 2011, the after-tax loss on natural gas-fired generating assets held for sale.  

NEE and NEER segregate into two categories unrealized mark-to-market gains and losses on energy derivative transactions which are used to manage commodity price risk.  The first category, referred to as non-qualifying hedges, represents certain transactions entered into as economic hedges but the transactions do not meet the requirements for hedge accounting or hedge accounting treatment is not elected.  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 which are required to be marked to market (such as the physical assets from which power is generated) are not marked to market.  As a consequence, NEE's net income reflects only the movement in one part of economically-linked transactions.  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, 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 or the capacity clause.  See Note 2.

37

In the third quarter of 2011, a subsidiary of NEER entered into an agreement to sell its ownership interest in four natural gas-fired generating plants with a total generating capacity of 2,152 mw.  In connection with the agreement to sell, during the three and nine months ended September 30, 2011, a loss of approximately $148 million ($97 million total after-tax with $91 million of this after-tax loss recorded by NEER) was recorded in NEE's condensed consolidated statements of income, which due to its nature and significance, was excluded from adjusted earnings.  See Note 3 - Nonrecurring Fair Value Measurements.  The sale of the four natural gas-fired generating plants discussed above and the sale of one additional natural gas-fired generating plant were completed in the fourth quarter of 2011.

The following table provides details of the adjustments considered in computing adjusted earnings discussed above.  

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(millions)
Net unrealized mark-to-market after-tax losses from non-qualifying hedge activity(a)	$	(130	)	$	(38	)	$	(28	)	$	(85	)
Income (loss) from OTTI after-tax losses on securities held in NEER's nuclear decommissioning funds, net of OTTI reversals	$	13		$	(9	)	$	30		$	(5	)
After-tax loss on natural gas-fired generating assets held for sale(b)	$	—		$	(97	)	$	—		$	(97	)

____________________

(a) For the three and nine months ended September 30, 2012, $131 million and $31 million, respectively, of losses are included in NEER's net income; the balance is included in Corporate and Other.  For the three and nine months ended September 30, 2011, $37 million and $84 million, respectively, of losses are included in NEER's net income; the balance is included in Corporate and Other.

(b) $91 million 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, as well as the reversal of previously recognized unrealized mark-to-market gains or losses as the underlying transactions were realized.  As a general rule, a gain (loss) in the non-qualifying hedge category 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.

RESULTS OF OPERATIONS

Summary

NEE's net income for the three months ended September 30, 2012 and 2011 was $415 million and $407 million, respectively, an increase of $8 million, and reflects the following:

• higher results at FPL of $45 million primarily due to investments in plant in service which resulted in higher use of FPL's surplus depreciation credit, as permitted under the terms of the stipulation and settlement agreement regarding FPL's base rates (2010 rate agreement), to earn an 11% return on common equity as determined for regulatory purposes (regulatory ROE) in 2012, higher cost recovery clause results and a higher equity component of AFUDC (AFUDC - equity),

partly offset by,

• lower results at NEER of $23 million primarily due to higher net unrealized mark-to-market losses from non-qualifying hedge activity and lower results from the existing asset portfolio, partly offset by the absence of a loss recorded in the prior year on natural gas-fired generating assets held for sale and improved results from the customer supply and proprietary power and gas trading businesses, and

• lower results at Corporate and Other of $14 million primarily due to an impairment charge on an early stage technology investment.

NEE's net income for the nine months ended September 30, 2012 and 2011 was $1,482 million and $1,256 million, respectively, an increase of $226 million, and reflects the following:

• higher results at FPL of $132 million primarily due to the reasons discussed above for the quarter, and

• higher results at NEER of $145 million primarily due to the absence of a loss recorded in the prior year on natural gas-fired generating assets held for sale, lower net unrealized mark-to-market losses from non-qualifying hedge activity and higher results from new investments, offset in part by lower results from the existing asset portfolio,

partly offset by,

• lower results at Corporate and Other of $51 million primarily due to lower consolidating income tax adjustments reflecting the absence of the state deferred income tax benefit recorded in 2011, higher interest expense and the impairment charge on an early stage technology investment.

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NEE's effective income tax rates for the three and nine months ended September 30, 2012 were approximately 27% and 27%, respectively; NEE's effective income tax rates for the corresponding periods in 2011 were 28% and 18%.  These rates 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 can be significantly affected by wind generation and by the expiration of PTCs after ten years of production.  PTCs for the three and nine months ended September 30, 2012 were approximately $35 million and $147 million, respectively, and $45 million and $208 million for the comparable periods in 2011.  Deferred income tax benefits associated with convertible ITCs for the three and nine months ended September 30, 2012 were approximately $14 million and $37 million, respectively, and $9 million and $17 million for the comparable periods in 2011.  NEE's effective income tax rate for the nine months ended September 30, 2011 was also reduced by the approximately $64 million state deferred income tax benefit recorded at Corporate and Other and the $26 million state ITC benefit.  See Note 5.

FPL:  Results of Operations

FPL’s net income for the three months ended September 30, 2012 and 2011 was $392 million and $347 million, respectively, an increase of $45 million.FPL’s net income for the nine months ended September 30, 2012 and 2011 was $984 million and $852 million, respectively, an increase of $132 million.  See Summary above for a discussion of the major drivers of these increases.

FPL's operating revenues consisted of the following:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
	(millions)
Retail base	$	1,243	$	1,263	$	3,264	$	3,261
Fuel cost recovery	1,131		1,312		2,916		3,421
Other cost recovery clauses and pass-through costs, net of any deferrals	536		514		1,416		1,346
Other, primarily pole attachment rentals, transmission and wholesale sales and customer-related fees	65		63		182		172
Total	$	2,975	$	3,152	$	7,778	$	8,200

Retail Base

As permitted by the 2010 rate agreement, for the nine months ended September 30, 2012, FPL collected approximately $52 million in additional retail base revenues through the capacity clause related to the placement in service of West County Energy Center (WCEC) Unit No. 3 in May 2011.  Additional base revenues of approximately $7 million and $17 million were collected during the three and nine months ended September 30, 2012, respectively, related to new nuclear capacity which was placed in service in 2011, as permitted by the FPSC's nuclear cost recovery rule.

Retail Customer Usage and Growth

For the three months ended September 30, 2012, FPL experienced a 3.5% decrease in average usage per retail customer, reflecting weather and other factors, which decreased retail base revenues by approximately $36 million.  For the nine months ended September 30, 2012, FPL experienced a 2.6% decrease in average usage per retail customer, reflecting weather and other factors, which decreased retail base revenues by approximately $86 million.  Usage per retail customer for the three and nine months ended September 30, 2011 includes two extra days of sales after adjusting for a change in 2011 from a fiscal month to a calendar month.  For the three and nine months ended September 30, 2012, FPL experienced a 0.7% and 0.6% increase, respectively, in the average number of customer accounts, which increased retail base revenues by approximately $9 million and $20 million, respectively.

Cost Recovery Clauses

For the three months ended September 30, 2012 and 2011, cost recovery clauses contributed $42 million and $28 million, respectively, to FPL’s net income; the amounts for the nine months ended September 30, 2012 and 2011 were $113 million and $76 million, respectively.  The increase in cost recovery clause results was primarily due to a return related to additional nuclear capacity investments.  In 2012, it is expected that cost recovery clauses will contribute higher earnings for FPL primarily as a result of additional nuclear capacity investments.  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 other operations and maintenance (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 and franchise fee costs are included in fuel, purchased power and interchange and taxes other than income taxes and other, respectively, in the condensed consolidated statements of income.

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Risk Management Fuel Procurement Program

FPL uses a risk management fuel procurement program which was approved by the FPSC.  The FPSC reviews the program activities and results for prudence on an annual basis as part of its annual review of fuel costs.  The program is intended to manage fuel price volatility by locking in fuel prices for a portion of FPL’s fuel requirements.  The current regulatory asset for the change in fair value of derivative instruments used in the fuel procurement program was approximately $59 million and $502 million at September 30, 2012 and December 31, 2011, respectively.

The decreasein fuel cost recovery revenues for the three months ended September 30, 2012 is primarily due to a lower average fuel factor of approximately $158 million and lower energy sales of $23 million.  The decreasein fuel cost recovery revenues for the nine months ended September 30, 2012 is primarily due to a lower average fuel factor of approximately $442 million and lower energy sales of $63 million.  The change from December 31, 2011 to September 30, 2012 in deferred clause and franchise expenses and deferred clause and franchise revenues was approximately $115 million and positively affected NEE’s and FPL’s cash flows from operating activities for the nine months ended September 30, 2012.

Other Items Impacting FPL Results

Fuel, Purchased Power and Interchange

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
	(millions)
Fuel and energy charges during the period	$	1,117	$	1,249	$	2,805	$	3,363
Net collection of previously deferred retail fuel costs	9		55		101		42
Other, primarily capacity charges, net of any capacity deferral	154		175		395		449
Total	$	1,280	$	1,479	$	3,301	$	3,854

The decrease in fuel and energy charges for the three months ended September 30, 2012 reflects lower fuel and energy prices of $99 million and lower energy sales of $33 million.The decrease in fuel and energy charges for the nine months ended September 30, 2012 reflects lower fuel and energy prices of $494 million and lower energy sales of $64 million.

O&M Expenses

FPL's O&M expenses increased $68 million for the nine months ended September 30, 2012, reflecting higher maintenance costs primarily due to the timing and extent of nuclear and fossil unit outages and higher insurance, restoration, tree trimming and employee-related costs.

Depreciation and Amortization Expense

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

	Three Months Ended September 30,					Nine Months Ended September 30,
	2012			2011		2012			2011
	(millions)
Surplus depreciation (credit) reversal recorded under the 2010 rate agreement	$	(33	)	$	47	$	(363	)	$	(84	)
Other depreciation and amortization recovered under base rates	254			239		756			699
Depreciation and amortization recovered under cost recovery clauses and securitized storm-recovery cost amortization	33			13		103			38
Total	$	254		$	299	$	496		$	653

Under the terms of the 2010 rate agreement, FPL can vary the amount of surplus depreciation credit taken to earn up to an 11% regulatory ROE. The increase in surplus depreciation recorded under the 2010 rate agreement for the three and nine months ended September 30, 2012 enabled FPL to earn its 11% regulatory ROE, primarily as a result of increased plant investment. As of September 30, 2012, approximately $222 million of surplus depreciation credit remained available for use in 2012.  For the three months ended September 30, 2011, FPL was required to reverse $47 million of the surplus depreciation credit taken earlier in 2011 in order to comply with the 2010 rate agreement.  The increase in other depreciation and amortization expense recovered under base rates for the three and nine months ended September 30, 2012 is primarily due to higher plant in service balances.  The increase in depreciation and amortization recovered under cost recovery clauses and securitized storm-recovery cost amortization for the three and nine months ended September 30, 2012 is primarily due to true ups of prior year recoveries under the FPSC's nuclear cost recovery rule.

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Interest Expense

The increase in interest expense for the three and nine months ended September 30, 2012 is primarily due to additional debt outstanding, partly offset by lower average interest rates and lower interest expense on customer deposits.

AFUDC - Equity

The increase in AFUDC - equity for the three and nine months ended September 30, 2012 is primarily due to additional AFUDC - equity on the Cape Canaveral and Riviera Beach modernization projects, partly offset for the nine months ended September 30, 2012 by the absence of AFUDC - equity on WCEC Unit No. 3, which was placed in service in May 2011.

FPL Rate Case

In March 2012, FPL filed a petition with the FPSC requesting, among other things, a base rate increase, on an annualized basis, of approximately $517 million effective January 2013 and an additional approximately $174 million commencing when FPL's modernized Cape Canaveral power plant becomes operational, which is expected to occur in June 2013.  FPL's requested increases are based on an allowed regulatory ROE of 11.50%, with a range of plus or minus 100 basis points, consisting of a base ROE of 11.25% and a 0.25% ROE performance adder conditioned on FPL maintaining the lowest typical residential customer bill among all the electric utilities in Florida based on a twelve-month average.  Additionally, FPL's petition proposed the continuation of the mechanism for recovery of future storm restoration costs provided under the 2010 rate agreement.  Hearings on the base rate proceeding were held during the third quarter of 2012.  The FPSC decision on this matter is pending the FPSC's decision on the proposed 2012 rate agreement described below.

In August 2012, FPL and several intervenors in FPL's base rate proceeding filed with the FPSC a joint motion for the FPSC to approve a stipulation and settlement signed by those parties (proposed 2012 rate agreement) that would resolve all matters in FPL's pending base rate proceeding.  Key elements of the proposed 2012 rate agreement, which would be effective from January 2013 through December 2016, include, among other things, the following:

• New retail base rates and charges would be established resulting in an increase in retail base revenues of $378 million on an annualized basis commencing in January 2013.

• FPL's allowed regulatory ROE would be 10.70%, with a range of plus or minus 100 basis points.  If FPL's earned regulatory ROE were to fall below 9.70%, FPL could seek retail base rate relief.  If the earned regulatory ROE were to rise above 11.70%, any party to the proposed 2012 rate agreement other than FPL could seek a review of FPL's retail base rates.

• Retail base rates would be increased by the annualized base revenue requirements for FPL's three modernization projects (Cape Canaveral, Riviera and Port Everglades) as each of the modernized units becomes operational (which is expected in 2013, 2014 and 2016, respectively).

• Subject to certain conditions, FPL could amortize, over the term of the proposed 2012 rate agreement, any surplus depreciation reserve remaining at the end of 2012 plus a portion of FPL's fossil dismantlement reserve (collectively, the reserve) in an aggregate amount not to exceed $400 million, provided that in any year of the proposed 2012 rate agreement, FPL would amortize at least enough reserve to maintain a 9.70% earned regulatory ROE but would not amortize any reserve that would result in an earned regulatory ROE in excess of 11.70%.

• Future storm restoration costs would be recoverable on an interim basis beginning 60 days from the filing of a cost recovery petition, but capped at an amount that could produce a surcharge of no more than $4 for every 1,000 kwh of usage on residential bills during the first 12 months of cost recovery.  Any additional costs would be eligible for recovery in subsequent years. If storm restoration costs were to exceed $800 million in any given calendar year, FPL could request an increase to the $4 surcharge to recover the amount above $800 million.

The proposed 2012 rate agreement is subject to FPSC approval. The State of Florida Office of Public Counsel opposes the proposed 2012 rate agreement and has petitioned the Florida Supreme Court to require the FPSC to terminate its consideration of the agreement. Hearings on the proposed 2012 rate agreement are scheduled for November 19-21, 2012.  The FPSC is expected to rule on that agreement by the end of 2012.

Major Capital Projects

In April 2012, the FPSC issued an order approving the modernization of FPL's Port Everglades power plant to a high-efficiency natural gas-fired approximately 1,280 mw unit, which is expected to be in service in mid-2016.  In May 2012, the Florida Industrial Power Users Group appealed the FPSC's order, which appeal will be heard by the Florida Supreme Court.  In addition, FPL is in the process of adding at least 526 mw of capacity at its existing nuclear units at St. Lucie and Turkey Point. The additional capacity is expected to be in service by the second quarter of 2013.

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NEER: Results of Operations

NEER’s net income for the three months ended September 30, 2012 and 2011 was $44 million and $67 million, respectively, a decrease of $23 million.  NEER’s net income for the nine months ended September 30, 2012 and 2011 was $516 million and $371 million, respectively, an increase of $145 million.  The primary drivers, on an after-tax basis, of these changes were as follows:

	Increase (Decrease) From Prior Period
	Three Months Ended September 30, 2012			Nine Months Ended September 30, 2012
	(millions)
New investments(a)	$	24		$	67
Existing assets:(a)
Wind	(6		)	(77		)
Merchant	(43		)	(59		)
Contracted	(38		)	(38		)
Total existing assets	(87		)	(174		)
Gas infrastructure(b)	(26		)	8
Customer supply and proprietary power and gas trading businesses(b)	56			47
Impairment charges in 2011	—			31
Interest expense, differential membership costs and other	(9		)	(13		)
Change in unrealized mark-to-market non-qualifying hedge activity(c)(d)	(94		)	53
Loss on natural gas-fired generating assets held for sale(e)	91			91
Change in OTTI losses on securities held in nuclear decommissioning funds, net of OTTI reversals(d)	22			35
Net income increase (decrease)	$	(23	)	$	145

_______________________

(a) Includes PTCs and state ITCs on wind projects and, for new investments, deferred income tax and other benefits associated with convertible ITCs but does not include 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) Does not include allocation of interest expense or corporate general and administrative expenses.

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

(d) See table in Overview for additional detail.

(e) See Note 3 - Nonrecurring Fair Value Measurements for additional information.

New Investments

Results from new investments for the three months ended September 30, 2012 reflect the following:

• the addition of approximately 486 mw of wind and 45 mw of solar generation during or after the three months ended September 30, 2011, and

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

Results from new investments for the nine months ended September 30, 2012 reflect the following:

• the addition of approximately 556 mw of wind and 45 mw of solar generation during or after the nine months ended September 30, 2011, and

• higher deferred income tax benefits associated with convertible ITCs of approximately $20 million,

partly offset by,

• lower after-tax benefits associated with convertible ITCs of $9 million from the sale of membership interests where the investors elected to receive the convertible ITCs related to the underlying wind project; the pretax amount of such benefit is reflected in taxes other than income taxes and other in NEE's condensed consolidated statements of income for the nine months ended September 30, 2011.

Existing Assets

Wind

For the three months ended September 30, 2012, results from NEER's existing wind asset portfolio decreased primarily due to the roll off of PTCs on certain wind projects after ten years of production (PTC roll off).  For the nine months ended September 30, 2012, results from NEER's existing wind asset portfolio decreased due to the absence of approximately $33 million of state ITC benefit recorded in the prior period and $35 million of PTC roll off, with the balance primarily attributable to a lower wind resource.

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Merchant

For the three months ended September 30, 2012, results from NEER's existing merchant asset portfolio decreased primarily due to:

• lower results at Seabrook of approximately $13 million primarily due to reduced capacity, lower priced hedges and higher O&M and depreciation expenses, partly offset by higher gains on decommissioning funds,

• lower results of $25 million in the Electric Reliability Council of Texas (ERCOT) region primarily due to market conditions as the prior year benefited from high market prices in August 2011, and

• lower hydro results of $4 million primarily due to a lower water resource and lower priced hedges.

For the nine months ended September 30, 2012, results from NEER's existing merchant asset portfolio decreased primarily due to:

• lower results at Seabrook of approximately $24 million primarily due to reduced capacity, lower priced hedges, lower gains on decommissioning funds and higher depreciation expense, partly offset by the absence of an extended refueling outage that occurred in 2011,

• lower results of $24 million in the ERCOT region primarily due to market conditions as the prior year benefited from high market prices in August 2011, and

• lower hydro results of $14 million primarily due to lower priced hedges and a lower water resource.

Contracted

For the three months ended September 30, 2012, results from NEER's existing contracted asset portfolio decreased primarily due to:

• the absence of earnings of approximately $25 million from certain natural gas-fired generating plants which were sold in the fourth quarter of 2011 (see Note 3 - Nonrecurring Fair Value Measurements), and

• lower results of $8 million at the Point Beach Nuclear Power Plant (Point Beach) primarily due to lower gains on decommissioning funds and higher O&M and depreciation expenses, partly offset by a higher contract price and the addition of approximately 83 mw of capacity which was completed in December 2011.

For the nine months ended September 30, 2012, results from NEER's existing contracted asset portfolio decreased primarily due to:

• the absence of earnings of approximately $34 million from the natural gas-fired generating plants which were sold in the fourth quarter of 2011, and

• lower results of $19 million related to the expiration of power sales agreements at certain joint venture projects, which is reflected in equity in earnings of equity method investees in NEE's condensed consolidated statements of income,

partly offset by,

• higher results of $14 million at Point Beach primarily due to the absence of a planned outage in the prior year and the addition of 167 mw of capacity, approximately one-half of which was completed in June 2011 and the other half of which was completed in December 2011, partly offset by higher O&M and depreciation expenses.

Gas Infrastructure

The decrease in gas infrastructure results for the three months ended September 30, 2012 reflects the absence of gains from exiting the hedged positions on a number of future gas production opportunities in 2011, partly offset by income from additional production in 2012.  The increase in gas infrastructure results for the nine months ended September 30, 2012 is primarily due to gains from exiting the hedged positions on a number of future gas production opportunities in the first quarter of 2012 and income from additional production, partly offset by the absence of gains from exiting the hedged positions on a number of future gas production opportunities which occurred in the third quarter of 2011.

Customer Supply and Proprietary Power and Gas Trading

Results from the customer supply and proprietary power and gas trading businesses for the three and nine months ended September 30, 2012 increased primarily due to improved market conditions in the third quarter of 2012.  Results for the nine-month period were partly offset by lower power and gas trading results and a decline in full requirement results as a result of warmer weather in the Northeast.

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Impairment Charges in 2011

Impairment charges taken in the prior year-to-date period relate to the write down to fair value of certain wind and oil-fired generation assets deemed to be unrecoverable, resulting in an impairment charge of $51 million which is recorded as a separate line item in NEE's condensed consolidated statements of income for the nine months ended September 30, 2011.  The after-tax amount of the impairment charge reduced NEER's results for the nine months ended September 30, 2011 by $31 million.  See Note 3 - Nonrecurring Fair Value Measurements.

Interest Expense, Differential Membership Costs and Other

For the three and nine months ended September 30, 2012, interest expense, differential membership costs and other reflects higher costs primarily due to growth of the business, partly offset for the nine-month period by a gain related to an investment previously accounted for under the equity method in which NEER obtained a controlling interest.

Other Factors

In addition 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 September 30, 2012 decreased $364 million primarily due to:

• the absence of revenues of approximately $159 million associated with five natural gas-fired generating plants sold in the fourth quarter of 2011,

• unrealized mark-to-market losses of $161 million from non-qualifying hedges compared to $32 million of such losses in 2011, and

• unfavorable market conditions primarily in the ERCOT and New England Power Pool (NEPOOL) regions and lower revenues at NextEra Energy Power Marketing, LLC (PMI) (collectively, $156 million),

partly offset by,

• higher revenues of $11 million at NEER's contracted nuclear facilities primarily due to favorable contract pricing and the addition of capacity at Point Beach, and

• higher revenues of $52 million from new investments.

Operating revenues for the nine months ended September 30, 2012 decreased $181 million primarily due to:

• the absence of revenues of approximately $402 million associated with five natural gas-fired generating plants sold in the fourth quarter of 2011, and

• unfavorable market conditions in the ERCOT and NEPOOL regions and lower revenues at PMI and the existing wind projects (collectively, $98 million),

partly offset by,

• higher revenues from new investments of $147 million,

• higher revenues of $92 million at NEER's contracted nuclear facilities primarily due to the absence of a 2011 planned outage, the addition of capacity at Point Beach and favorable contract pricing, and

• unrealized mark-to-market gains of $62 million from non-qualifying hedges compared to $13 million of losses on such hedges in 2011.

Operating Expenses

Operating expenses for the three months ended September 30, 2012 decreased $135 million primarily due to the absence of operating expenses associated with five natural gas-fired generating plants sold in the fourth quarter of 2011.

Operating expenses for the nine months ended September 30, 2012 decreased $319 million primarily due to:

• the absence of operating expenses associated with five natural gas-fired generating plants sold in the fourth quarter of 2011, and

• the absence of the $51 million impairment charge recorded in 2011.

Interest Expense

NEER's interest expense for the three and nine months ended September 30, 2012 decreased $16 million and $34 million, respectively, primarily due to lower average interest rates.

Gains on Disposal of Assets - net

Gains on disposal of assets - net in NEE’s condensed consolidated statements of income for the three and nine months ended September 30, 2012 and 2011 primarily reflect gains on sales of securities held in NEER’s nuclear decommissioning funds.

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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.  Also see Summary above and Note 5 for a discussion of PTCs and deferred income tax benefits associated with convertible ITCs.

Wind and Solar Construction

NEER plans to add approximately 1,500 mw of new U.S. wind generation in 2012, including 257 mw added through September 30, 2012, 100 mw of new U.S. wind generation in 2013 and approximately 600 mw of new wind generation in Canada between 2012 and 2015.  NEER plans to add approximately 900 mw of new solar generation during the period 2012 through 2016, including 40 mw acquired in the first quarter of 2012.

In its development and operation of U.S. wind generation facilities, NEER depends heavily on the federal PTC, which currently provides an income tax credit for the production of electricity from utility-scale wind turbines for the first ten years of commercial operation.This incentive was created under the Energy Policy Act of 1992 and is set to expire such that it will not apply to new wind projects that first achieve commercial operation after December 31, 2012.  Wind and solar project developers also can choose to receive a 30% ITC, which would be in place of the PTC in the case of wind projects.  To be eligible, a project must achieve commercial operation before 2013 in the case of wind and before 2017 in the case of solar.  For projects placed in service before 2013 in the case of wind or before 2017 in the case of solar, in each case at which construction began before the end of 2011, developers can elect to receive an equivalent cash payment from the U.S. Department of Treasury for the value of the 30% ITC.Any failure to renew the PTC or adopt other legislation conducive to the economic development of wind and solar generation facilities in the U.S. could impede NEER's ability to economically develop wind and solar energy projects in the U.S. and could have a material adverse effect on NEE's business, financial condition, results of operations and prospects. Any renewal or new conducive legislative actions are currently uncertain.

In addition, Spain is considering the imposition of new taxes on energy generation and other changes to the economic framework of renewable energy projects, including the 99.8 mw of solar thermal facilities that NEER is constructing in Spain.  If the proposed legislation were enacted into law, management believes that it would result in reduced project returns and the need to contribute additional equity in the project, neither of which is expected to have a significant effect on NEE's business, financial condition, results of operations and prospects.  The economic and operational impact to NEER's project will depend on the structure of the final legislation.

Corporate and Other: Results of Operations

Corporate and Other is primarily comprised of interest expense, the operating results of FPL FiberNet, Lone Star 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 deferred credit 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 September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(millions)
Interest expense, net of allocations to NEER	$	(24	)	$	(19	)	$	(68	)	$	(51	)
Interest income	10			9			27			24
Federal and state income tax benefits	4			(1		)	18			40
Other	(11		)	4			5			20
Net income (loss)	$	(21	)	$	(7	)	$	(18	)	$	33

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The increase in interest expense, net of allocations to NEER, for the three- and nine-month periods reflects a lower allocation of interest costs to NEER, as NEER has obtained additional project-specific financing, and higher debt outstanding, partly offset by lower average interest rates.  The federal and state income tax benefits reflect consolidating income tax adjustments and, for the three and nine months ended September 30, 2011, include an approximately $6 million expense associated with the loss on natural gas-fired generating assets held for sale.  Also, federal and state income tax benefits for the nine months ended September 30, 2011 include the state deferred income tax benefit of approximately $64 million related to state tax law changes in 2011.  Other includes all other corporate income and expenses, as well as other business activities.  The decline in other for the three and nine months ended September 30, 2012 is primarily due to a $13 million after-tax impairment charge on an early stage technology investment; the pretax amount ($20 million) of such impairment is reflected in other - net in NEE's condensed consolidated statements of income.

Lone Star Rate Case

In October 2012, the Public Utility Commission of Texas (PUCT) reached a decision in Lone Star's initial rate case proceeding.  The PUCT decision was to approve an annual revenue requirement for approximately $50 million of capital investment and O&M expenses.  The annual revenue requirement reflects, among other things, an equity ratio of 40% and an allowed regulatory ROE of 9.6%.  The remaining capital investment will be included in rates through an interim rate adjustment mechanism.  In addition, Lone Star must file a general rate case, with a full 12-month historical test year, within four months of having 12 months of historical operating data, which is expected to occur in the second or third quarter of 2014.

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 flow from operations, short- and long-term borrowings, and the issuance, from time to time, of short- and long-term debt and equity securities, consistent with NEE’s and FPL’s objective of maintaining, on a long-term basis, a capital structure that will support a 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.

46

Cash Flows

Sources and uses of NEE's and FPL's cash for the nine months ended September 30, 2012 and 2011 were as follows:

	NEE						FPL
	Nine Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(millions)
Sources of cash:
Cash flows from operating activities	$	3,157		$	3,117		$	2,302		$	1,748
Long-term borrowings and change in loan proceeds restricted for construction	4,438			2,321			594			248
Proceeds from the sale of differential membership interests, net of payments to investors	361			210			—			—
Capital contribution from NEE	—			—			240			310
Cash grants under the Recovery Act	105			503			—			202
Issuances of common stock - net	386			39			—			—
Net increase in short-term debt	396			946			142			307
Other sources - net	15			91			36			42
Total sources of cash	8,858			7,227			3,314			2,857
Uses of cash:
Capital expenditures and independent power and other investments and nuclear fuel purchases	(6,689		)	(4,317		)	(3,198		)	(2,351		)
Retirements of long-term debt	(1,321		)	(1,688		)	(50		)	(45		)
Dividends	(752		)	(689		)	—			(400		)
Repurchases of common stock	(19		)	—			—			—
Other uses - net	(208		)	(195		)	(82		)	(51		)
Total uses of cash	(8,989		)	(6,889		)	(3,330		)	(2,847		)
Net increase (decrease) in cash and cash equivalents	$	(131	)	$	338		$	(16	)	$	10

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 nine months ended September 30, 2012 and 2011.

	Nine Months Ended September 30,
	2012		2011
	(millions)
FPL:
Generation:
New	$	1,852	$	943
Existing	428		595
Transmission and distribution	692		566
Nuclear fuel	137		223
General and other	57		169
Other, primarily the exclusion of AFUDC - equity and change in accrued property additions	32		(145		)
Total	3,198		2,351
NEER:
Wind	1,498		637
Solar	929		317
Nuclear, including nuclear fuel	203		479
Other	460		329
Total	3,090		1,762
Corporate and Other	401		204
Total capital expenditures and independent power and other investments and nuclear fuel purchases	$	6,689	$	4,317

47

Liquidity

At September 30, 2012, NEE's total net available liquidity was approximately $5.5 billion, of which FPL's portion was approximately $2.8 billion.  The table below provides the components of FPL's and NEECH's net available liquidity at September 30, 2012:

										Maturity Date
	FPL			NEECH			Total			FPL	NEECH
				(millions)
Bank revolving line of credit facilities(a)	$	3,014		$	4,569		$	7,583		(b)	(b)
Less letters of credit	(3		)	(1,207		)	(1,210		)
	3,011			3,362			6,373
Revolving credit facility	235			—			235			2014
Less borrowings	—			—			—
	235			—			235
Letter of credit facility(c)	—			200			200				2015
Less letters of credit	—			—			—
	—			200			200
Subtotal	3,246			3,562			6,808
Cash and cash equivalents	20			226			246
Less commercial paper and short-term debt	(472		)	(1,102		)	(1,574		)
Net available liquidity	$	2,794		$	2,686		$	5,480

_______________________

(a) Provide for the funding of loans up to $7,583 million ($3,014 million for FPL) and the issuance of letters of credit up to $4,083 million ($1,564 million for FPL).  The entire amount of the credit facilities is available for general corporate purposes, including to provide back-up liquidity for FPL’s and NEECH’s commercial paper programs and other short-term borrowings 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 in the event they are tendered by individual bond holders and not remarketed prior to maturity.

(b) Approximately $1,114 million of FPL's and $1,469 million of NEECH's bank revolving line of credit facilities expire in 2013.  The remaining portion of bank revolving line of credit facilities for FPL and NEECH expires in 2017.

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

Additionally, at September 30, 2012, certain subsidiaries of NEE had credit or loan facilities with available liquidity as follows:

	Original Amount	Amount Remaining Available at September 30, 2012	Rate	Maturity Date	Related Project Use
	(millions)
NEECH and NEER:
Canadian bank revolving credit agreements(a)(b)	C$300	$2	Variable	2013	Canadian renewable generating assets
Revolving loan agreement(a)	€170	$92	Variable	2014	Construction of Spain solar project
NEER:
Senior secured limited-recourse loan agreement(c)(d)	€589	$233	Variable	2030	Construction of Spain solar project
Term loan facility(c)(d)	$150	$150	Variable	2019	Construction of Genesis solar project
Lone Star:
Senior secured limited-recourse loan agreement(c)(e)	$387	$129	Variable	2016	Construction of Lone Star transmission line and substations

_____________________

(a) Includes, as a precondition to borrowing or issuing letters of credit, as well as default and related payment acceleration, provisions that require NEE's ratio of funded debt to total capitalization to not exceed a stated ratio.  Payment obligations are guaranteed by NEE pursuant to the 1998 guarantee agreement with NEECH.

(b) Available for general corporate purposes; the current intent is for it to be used for the purchase, development, construction, and/or operation of Canadian renewable generating assets.

(c) Includes default and related payment acceleration provisions for, among other things, failure to comply with certain covenants, including requirements that construction of the project must be completed by a certain date.

(d) Borrowings are preconditioned on equity being contributed by the project's parent, and are drawn on a pro-rata basis with those equity contributions.  The total equity funding commitment and, until certain conditions or obligations related to the project are met, certain obligations, including all or a portion of the debt payment obligations, are guaranteed by NEECH, which guarantee obligations are in turn guaranteed by NEE.  The related NEECH guarantee contains default and acceleration provisions relating to, among other things, NEE's ratio of funded debt to total capitalization exceeding a specified ratio.

(e) Borrowings are preconditioned on equity being contributed by Lone Star's parent, and are drawn on a pro-rata basis with those equity contributions.  The total equity funding commitment has been guaranteed by NEECH, which guarantee obligations are in turn guaranteed by NEE.  The related NEECH guarantee contains default provisions and related provisions for acceleration of the unfunded equity commitment relating to, among other things, NEE's ratio of funded debt to total capitalization exceeding a specified ratio.

48

In October 2012, an indirect wholly-owned subsidiary of NEER (the borrower) and NEECH entered into a Canadian $150 million principal amount variable rate, bank revolving loan agreement maturing in October 2014, which amended an existing loan agreement that was scheduled to mature in March 2013. The loan agreement provides funding for the borrower's general corporate purposes, including funding loans to various affiliates for the purchase, development, construction, and/or operation of Canadian renewable generating assets.  NEECH has guaranteed the repayment of all borrowings and interest under the revolving loan agreement, which guarantee obligation is in turn guaranteed by NEE pursuant to a 1998 guarantee agreement with NEECH.  As a precondition to the borrower's ability to borrow under the terms of the revolving loan agreement, NEE must, among other things, maintain a ratio of funded debt to total capitalization that does not exceed a stated ratio.  The revolving loan agreement also contains default and related acceleration provisions for, among other things, a failure by NEE to satisfy the ratio requirement.  At October 25, 2012, approximately Canadian $119 million (approximately $121 million) of the funding commitment under the revolving loan agreement remains available.

An indirect wholly-owned subsidiary of NEER has experienced lower operating cash flows, primarily due to low energy prices in the Northeast, and is not expected to make an interest payment due in January 2013 on certain debt associated with a hydro project.  If the related debt agreement is not restructured and the interest payment is not made timely, the subsidiary could be in default and potentially face bankruptcy.  This potential default is not expected to have a material adverse effect on NEE's future financial results or operations.

Dodd-Frank Act

NEE and FPL continue to monitor the development of rules related to the Dodd-Frank Act and are implementing those rules that affect their businesses.  A number of rules have already been finalized and have become or will become effective over the next 12 months.  In July 2012, the U.S. Commodity Futures Trading Commission voted to finalize a rule related to the definition of a swap.  The effective date of this rule was October 12, 2012, resulting in formal effective dates for a number of other rules that are dependent on the definition of a swap over the next 12 months, including the reporting and recordkeeping obligations applicable to derivative end users such as NEE and FPL.  The implementation of these rules is not expected to have a material effect on NEE and FPL, however, it is expected to add cost and compliance risk related to hedging activities.  The rules related to collateral requirements have not been finalized.  If those rules, when finalized, require NEE and FPL to post significant amounts of cash collateral with respect to swap transactions, NEE's and FPL's liquidity could be materially affected.

NEE and FPL cannot predict the impact these new rules will have on their ability to hedge their commodity and interest rate risks or on the OTC derivatives market as a whole, but management believes that they could potentially have a material effect on NEE's and FPL's risk exposure and financial results, as well as reduce market liquidity and further increase the cost of hedging activities.

Capital Support

Letters of Credit, Surety Bonds and Guarantees

NEE and FPL obtain letters of credit and surety bonds and issue guaranteesto 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, nuclear activities, capital expenditures for NEER's wind and solar development and other contractual agreements.

In addition, as part of contract negotiations in the normal course of business, NEE and 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.

At September 30, 2012, NEE had approximately $1.3 billion of standby letters of credit ($3 million for FPL), approximately $170 million of surety bonds ($54 million for FPL) and approximately $13.6 billion notional amount of guarantees and indemnifications ($22 million for FPL), of which approximately $8 billion ($10 million for FPL) letters of credit, guarantees and indemnifications have expiration dates within the next five years.  An aggregate of approximately $1.2 billion ($3 million for FPL) of the standby letters of credit at September 30, 2012 were issued under FPL’s and NEECH’s credit facilities.

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 September 30, 2012, NEE and FPL did not have any liabilities recorded for these letters of credit, surety bonds, guarantees and indemnifications.

49

Shelf Registration

In August 2012, NEE, NEECH and FPL filed a shelf registration statement with the SEC for an unspecified amount of securities which became effective upon filing.  The amount of securities issuable by the companies is established from time to time by their respective boards of directors.  As of October 25, 2012, securities that may be issued under the registration statement include, depending on the registrant, senior debt securities, subordinated debt securities, junior subordinated debentures, first mortgage bonds, common stock, preferred stock, stock purchase contracts, stock purchase units, warrants and guarantees related to certain of those securities.  As of October 25, 2012, NEE and NEECH had approximately $2.2 billion (issuable by either or both of them up to such aggregate amount) of board-authorized available capacity, and FPL had $150 million of board-authorized available capacity.

Energy Marketing and Trading and Market Risk Sensitivity

NEE and FPL are exposed to risks associated with adverse changes in commodity prices, interest rates, equity prices and currency exchange rates.  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, equity prices or currency exchange rates 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 power generation 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 and nine months ended September 30, 2012 were as follows:

			Hedges on Owned Assets
	Trading		Non- Qualifying			OCI			FPL Cost Recovery Clauses			NEE Total
	(millions)
Three months ended September 30, 2012
Fair value of contracts outstanding at June 30, 2012	$	113	$	899		$	4		$	(302	)	$	714
Reclassification to realized at settlement of contracts	24		27			(2		)	185			234
Inception value of new contracts	6		—			—			—			6
Net option premium purchases (issuances)	13		—			—			—			13
Changes in fair value excluding reclassification to realized	33		(254		)	—			90			(131		)
Fair value of contracts outstanding at September 30, 2012	189		672			2			(27		)	836
Net margin cash collateral paid (received)												(120		)
Total mark-to-market energy contract net assets (liabilities) at September 30, 2012	$	189	$	672		$	2		$	(27	)	$	716

50

				Hedges on Owned Assets
	Trading			Non- Qualifying			OCI			FPL Cost Recovery Clauses			NEE Total
	(millions)
Nine months ended September 30, 2012
Fair value of contracts outstanding at December 31, 2011	$	15		$	720		$	8		$	(501	)	$	242
Reclassification to realized at settlement of contracts	49			(63		)	(6		)	560			540
Inception value of new contracts	6			2			—			—			8
Net option premium purchases (issuances)	(9		)	1			—			—			(8		)
Changes in fair value excluding reclassification to realized	128			12			—			(86		)	54
Fair value of contracts outstanding at September 30, 2012	189			672			2			(27		)	836
Net margin cash collateral paid (received)													(120		)
Total mark-to-market energy contract net assets (liabilities) at September 30, 2012	$	189		$	672		$	2		$	(27	)	$	716

NEE's total mark-to-market energy contract net assets (liabilities) at September 30, 2012 shown above are included on the condensed consolidated balance sheets as follows:

	September 30, 2012
	(millions)
Current derivative assets	$	456
Noncurrent derivative assets	875
Current derivative liabilities	(384		)
Noncurrent derivative liabilities	(231		)
NEE's total mark-to-market energy contract net assets	$	716

The sources of fair value estimates and maturity of energy contract derivative instruments at September 30, 2012 were as follows:

	Maturity
	2012			2013			2014			2015		2016		Thereafter		Total
	(millions)
Trading:
Quoted prices in active markets for identical assets	$	15		$	(79	)	$	4		$	6	$	—	$	—	$	(54	)
Significant other observable inputs	(53		)	47			5			22		30		29		80
Significant unobservable inputs	27			39			39			22		16		20		163
Total	(11		)	7			48			50		46		49		189
Owned Assets - Non-Qualifying:
Quoted prices in active markets for identical assets	(3		)	(2		)	(2		)	3		—		—		(4		)
Significant other observable inputs	59			78			66			69		77		13		362
Significant unobservable inputs	13			1			26			37		40		197		314
Total	69			77			90			109		117		210		672
Owned Assets - OCI:
Quoted prices in active markets for identical assets	4			—			—			—		—		—		4
Significant other observable inputs	(2		)	—			—			—		—		—		(2		)
Significant unobservable inputs	—			—			—			—		—		—		—
Total	2			—			—			—		—		—		2
Owned Assets - FPL Cost Recovery Clauses:
Quoted prices in active markets for identical assets	—			—			—			—		—		—		—
Significant other observable inputs	(110		)	78			—			—		—		—		(32		)
Significant unobservable inputs	1			3			1			—		—		—		5
Total	(109		)	81			1			—		—		—		(27		)
Total sources of fair value	$	(49	)	$	165		$	139		$	159	$	163	$	259	$	836

51

The changes in the fair value of NEE's consolidated subsidiaries' energy contract derivative instruments for the three and nine months ended September 30, 2011 were as follows:

				Hedges on Owned Assets
	Trading			Non- Qualifying			OCI			FPL Cost Recovery Clauses			NEE Total
	(millions)
Three months ended September 30, 2011
Fair value of contracts outstanding at June 30, 2011	$	9		$	352		$	30		$	(140	)	$	251
Reclassification to realized at settlement of contracts	(15		)	(16		)	(11		)	85			43
Net option premium purchases (issuances)	(46		)	—			—			—			(46		)
Changes in fair value excluding reclassification to realized	22			(63		)	—			(233		)	(274		)
Fair value of contracts outstanding at September 30, 2011	(30		)	273			19			(288		)	(26		)
Net margin cash collateral paid (received)													90
Total mark-to-market energy contract net assets (liabilities) at September 30, 2011	$	(30	)	$	273		$	19		$	(288	)	$	64

				Hedges on Owned Assets
	Trading			Non- Qualifying			OCI			FPL Cost Recovery Clauses			NEE Total
	(millions)
Nine months ended September 30, 2011
Fair value of contracts outstanding at December 31, 2010	$	25		$	422		$	49		$	(236	)	$	260
Reclassification to realized at settlement of contracts	(13		)	(74		)	(30		)	248			131
Net option premium purchases (issuances)	(77		)	—			—			—			(77		)
Changes in fair value excluding reclassification to realized	35			(75		)	—			(300		)	(340		)
Fair value of contracts outstanding at September 30, 2011	(30		)	273			19			(288		)	(26		)
Net margin cash collateral paid (received)													90
Total mark-to-market energy contract net assets (liabilities) at September 30, 2011	$	(30	)	$	273		$	19		$	(288	)	$	64

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 September 30, 2012 and December 31, 2011, the VaR figures are as follows:

	Trading						Non-Qualifying Hedges and Hedges in OCI and FPL Cost Recovery Clauses(a)						Total
	FPL		NEER		NEE		FPL		NEER		NEE		FPL		NEER		NEE
									(millions)
December 31, 2011	$	—	$	2	$	2	$	38	$	50	$	25	$	38	$	50	$	26
September 30, 2012	$	—	$	1	$	1	$	35	$	70	$	52	$	35	$	69	$	51
Average for the nine months ended September 30, 2012	$	—	$	2	$	2	$	42	$	60	$	45	$	42	$	60	$	45

______________________

(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 OCI and FPL cost recovery clauses category do not represent the economic exposure to commodity price movements.

52

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 swaps and using a combination of fixed rate and variable rate debt.  Interest rate swaps 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:

	September 30, 2012							December 31, 2011
	Carrying Amount			Estimated Fair Value				Carrying Amount			Estimated Fair Value
	(millions)
NEE:
Fixed income securities:
Special use funds	$	2,046		$	2,046		(a)	$	1,897		$	1,897		(a)
Other investments:
Notes receivable	$	500		$	681		(b)	$	503		$	535		(b)
Debt securities	$	115		$	115		(a)	$	89		$	89		(a)
Long-term debt, including current maturities	$	24,769		$	27,674		(c)	$	21,614		$	23,699		(c)
Interest rate swaps - net unrealized losses	$	(311	)	$	(311	)	(d)	$	(283	)	$	(283	)	(d)
FPL:
Fixed income securities - special use funds	$	1,609		$	1,609		(a)	$	1,499		$	1,499		(a)
Long-term debt, including current maturities	$	8,084		$	9,984		(c)	$	7,533		$	9,078		(c)

————————————

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

(b) 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).

53

At September 30, 2012, the estimated fair value of NEE's interest rate swaps was as follows:

Notional Amount	Effective Date	Maturity Date	Rate Paid	Rate Received	Estimated Fair Value
(millions)					(millions)
Fair value hedges - NEECH:
$250	May 2010	November 2013	Variable(a)	2.55%	$	5
$400	August 2010	September 2015	Variable(b)	2.60%	15
$250	August 2011	June 2013	Variable(c)	5.35%	(2		)
$500	August 2011	December 2015	Variable(d)	7.875%	1
$500	August 2011	March 2019	Variable(e)	6.00%	26
$400	August 2011	June 2021	Variable(f)	4.50%	28
Total fair value hedges					73
Cash flow hedges:
NEER:
$25	December 2003	December 2017	4.245%	Variable(g)	(3		)
$8	April 2004	December 2017	3.845%	Variable(g)	(1		)
$115	December 2005	November 2019	4.905%	Variable(g)	(13		)
$285	January 2007	January 2022	5.390%	Variable(h)	(33		)
$275	January 2009	December 2016	2.680%	Variable(g)	(18		)
$124	January 2009(i)	December 2023	3.725%	Variable(g)	(5		)
$78	January 2009	December 2023	2.578%	Variable(j)	(3		)
$16	March 2009	December 2016	2.655%	Variable(g)	(1		)
$7	March 2009(i)	December 2023	3.960%	Variable(g)	—
$266	May 2009	May 2017	3.015%	Variable(g)	(22		)
$106	May 2009(i)	May 2024	4.663%	Variable(g)	(6		)
$232	April 2010	January 2027	4.040%	Variable(h)	(38		)
$264	October 2010	September 2028	2.822%	Variable(g)	(25		)
$444	April 2011	December 2013	2.733%	Variable(k)	(17		)
$758	April 2011(i)	June 2018	4.042%	Variable(l)	(82		)
$627	April 2011(i)	December 2030	4.694%	Variable(l)	(64		)
$60	August 2011	January 2016	(m)	Variable(g)	(1		)
$209	December 2011	December 2029	2.275%	Variable(g)	(10		)
$81	July 2012	December 2014	0.667%	Variable(g)	—
$220	September 2012(i)	December 2030	2.095%	Variable(g)	(5		)
NEECH:
$250	October 2010(i)	June 2023	3.479%	Variable(g)	(37		)
Total cash flow hedges					(384		)
Total interest rate swaps					$	(311	)

————————————

(a) Three-month London InterBank Offered Rate (LIBOR) plus 0.4726%.

(b) Three-month LIBOR plus 0.7980%.

(c) Three-month LIBOR plus 4.8275%.

(d) Three-month LIBOR plus 6.675%.

(e) Three-month LIBOR plus 3.945%.

(f) Three-month LIBOR plus 2.05%.

(g) Three-month LIBOR.

(h) Six-month LIBOR.

(i) Exchange of payments does not begin until December 2016, December 2016, May 2017, December 2013, June 2018, December 2012 and June 2013, respectively.

(j) Three-month Banker's Acceptance Rate.

(k) One-month Euro Interbank Offered Rate (Euribor).

(l) Six-month Euribor.

(m) Rate varies over time from 0.4914% to 3.0048%.

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 $1,020 million ($459 million for FPL) at September 30, 2012.

54

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 $2,177 million and $1,970 million ($1,358 million and $1,238 million for FPL) atSeptember 30, 2012 and December 31, 2011, respectively.  At September 30, 2012, a hypothetical 10% decrease in the prices quoted by stock exchanges, which is a reasonable near-term market change, would result in a $207 million ($131 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.

Currency Exchange Rate Risk

At September 30, 2012, with respect to certain debt issuances and borrowings, NEECH has two cross currency swaps to hedge against currency movements with respect to both interest and principal payments.  At September 30, 2012 and December 31, 2011, the fair value of cross currency swaps was approximately $5 million and $18 million, respectively.

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 September 30, 2012, 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.

55

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 September 30, 2012, 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 chief financial officer of each of NEE and FPL concluded that the company's disclosure controls and procedures were effective as of September 30, 2012.

(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 14 - Legal Proceedings to Consolidated Financial Statements in the 2011 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 March 2012 Form 10-Q and 2011 Form 10-K. The factors discussed in Part II, Item 1A. Risk Factors in the March 2012 Form 10-Q and in Part I, Item 1A. Risk Factors in the 2011 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 March 2012 Form 10-Q and 2011 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 September 30, 2012 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)
7/1/12 - 7/31/12	—	$	—	—	13,274,748
8/1/12 - 8/31/12	5,245	$	69.23	—	13,274,748
9/1/12 - 9/30/12	530	$	67.48	—	13,274,748
Total	5,775	$	69.07	—

————————————

(a) Includes: (1) in August 2012, 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 September 2012, 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.

56

Item 5. Other Information

(a) None

(b) None

(c) Other events

(i) Reference is made to Item 1. Business - NEE's Operating Subsidiaries - NEER - Generation and Other Operations - Nuclear Facilities in the 2011 Form 10-K.

NEER sells substantially all of its share of the output of Duane Arnold under a long-term contract which expires in February 2014.  In July 2012, NEER executed a long-term contract to sell all of its share of the output of Duane Arnold to Interstate Power & Light Company under a long-term contract from February 2014 through February 2025. The new contract is subject to the approval of the Iowa Utilities Board.

(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 2011 Form 10-K.

In August 2012, the U.S. Court of Appeals for the District of Columbia (D.C. Circuit) vacated CSAPR and remanded it back to the U.S. Environmental Protection Agency (EPA) for further rulemaking.  The D.C. Circuit ordered that the EPA's CAIR remain in place until such time that the EPA promulgates a valid replacement.  The impact of complying with CAIR has not had and is not expected to have a significant effect on the financial results of NEE or FPL. Several petitioners, including the EPA, have filed for rehearing and the case is pending review by the D.C. Circuit, the timing and ultimate outcome of which is uncertain at this time.

(iii) Reference is made to Item 2. Properties - Generating Facilities - FPL in the 2011 Form 10-K.

In the fourth quarter of 2012, FPL intends to begin retiring and dismantling Cutler Units Nos. 5 and 6, Sanford Unit No. 3 and Port Everglades Units Nos. 1 through 4.  At September 30, 2012, approximately $514 million and $445 million is included in plant in service and other property and accumulated depreciation and amortization, respectively, on FPL's balance sheets (electric utility plant in service and other property and accumulated depreciation and amortization, respectively, for NEE)  related to these three plants, of which $437 million and $377 million, respectively, relate to Port Everglades Units Nos. 1 through 4.  Upon retirement of each plant, FPL expects to reclassify the net book value of each plant to a regulatory asset and amortize it over a four-year period in accordance with the capital recovery schedule mechanism FPL is seeking in its current base rate proceeding.

57

Item 6.  Exhibits

Exhibit Number	Description	NEE	FPL
*4(a)	Purchase Contract Agreement dated as of September 1, 2012, between NextEra Energy, Inc. and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(a) to Form 8-K dated September 11, 2012, File No. 1-8841)	x
*4(b)	Pledge Agreement, dated as of September 1, 2012, between NextEra Energy, Inc., Deutsche Bank Trust Company Americas, as Collateral Agent, Custodial Agent and Securities Intermediary, and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(b) to Form 8-K dated September 11, 2012, File No. 1-8841)	x
*4(c)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated September 11, 2012, creating the Series F Debentures due September 1, 2017 (filed as Exhibit 4(c) to Form 8-K dated September 11, 2012, File No. 1-8841)	x
*4(d)	Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated September 21, 2012, creating the 1.20% Debentures, Series due June 1, 2015 (filed as Exhibit 4 to Form 8-K dated September 21, 2012, File No. 1-8841)	x
4(e)	First Supplemental Indenture to Indenture (For Unsecured Debt Securities) dated as of June 1, 1999, dated as of September 21, 2012, between NextEra Energy Capital Holdings, Inc. and The Bank of New York Mellon, as Trustee	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.

58

		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:	October 25, 2012
		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)

59

EX-4.E

Exhibit 4(e)

FIRST SUPPLEMENTAL INDENTURE

To

Indenture (For Unsecured Debt Securities), dated as of June 1, 1999

Dated as of September 21, 2012

First Supplemental Indenture, dated as of September 21, 2012, between NextEra Energy Capital Holdings, Inc., a corporation duly organized and existing under the laws of the State of Florida (formerly known as FPL Group Capital Inc and referred to herein as the “Company”) and The Bank of New York Mellon, a New York banking corporation, as trustee (formerly known as The Bank of New York and referred to herein as the “Trustee”) under that certain Indenture (For Unsecured Debt Securities), dated as of June 1, 1999, between the Company and the Trustee, as it has been supplemented to date and as it will be supplemented hereby (the “Indenture”).

Whereas, the Company issued the following Securities under the Indenture:

$250,000,000 aggregate principal amount of the Company's 5.35% Debentures, Series due June 15, 2013, all of which remain Outstanding as of the date hereof;

$500,000,000 aggregate principal amount of the Company's 7-7/8% Debentures, Series due December 15, 2015, all of which remain Outstanding as of the date hereof;

$500,000,000 aggregate principal amount of the Company's 6.00% Debentures, Series due March 1, 2019, all of which remain Outstanding as of the date hereof;

$350,000,000 aggregate principal amount of the Company's Series C Debentures due June 1, 2014, all of which remain Outstanding as of the date hereof;

$200,000,000 aggregate principal amount of the Company's Floating Rate Debentures, Series due November 9, 2012, all of which remain Outstanding as of the date hereof;

$250,000,000 aggregate principal amount of the Company's 2.55% Debentures, Series due November 15, 2013, all of which remain Outstanding as of the date hereof;

$400,000,000 aggregate principal amount of the Company's 2.60% Debentures, Series due September 1, 2015, all of which remain Outstanding as of the date hereof;

$402,500,000 aggregate principal amount of the Company's Series D Debentures due September 1, 2015, all of which remain Outstanding as of the date hereof;

$400,000,000 aggregate principal amount of the Company's 4.50% Debentures, Series due June 1, 2021, all of which remain Outstanding as of the date hereof

$600,000,000 aggregate principal amount of the Company's Series E Debentures due June 1, 2017, all of which remain Outstanding as of the date hereof; and

$650,000,000 aggregate principal amount of the Company's Series F Debentures due September 1, 2017, all of which remain Outstanding as of the date hereof.

Whereas, pursuant to Section 1201 of the Indenture, the Company and the Trustee may enter into an indenture supplemental to the Indenture for one or more of the purposes set forth in such Section 1201 without the consent of the Holders of any of the Securities at the time Outstanding, including to cure any ambiguity, to correct or supplement any provision in the Indenture which may be defective or inconsistent with any other provision in the Indenture, or to make any other changes to the provisions of the Indenture or to add other provisions with respect to matters or questions arising under the Indenture, providedthat such other changes or additions shall not adversely affect the interests of the Holders of Securities of any series in any material respect.

Whereas, this First Supplemental Indenture adds agreements between the parties hereto regarding matters arising under the Indenture, which agreements will not adversely affect the interests of the Holders of Securities of any series in any material respect.

Now, Therefore, in consideration of the foregoing premises, the parties mutually agree as follows:

ARTICLE I

DEFINITIONS

Section 1.1Definitions. Except as otherwise defined herein, capitalized terms defined in the Indenture are used herein as therein defined.

ARTICLE II

SUPPLEMENT TO THE INDENTURE

Section 2.1Supplemental Agreements. The Indenture is hereby supplemented as follows:

(a)Electronic Instructions Given to the Trustee pursuant to the Indenture. As between the parties hereto, the Trustee agrees to accept and act upon instructions or directions pursuant to the Indenture sent by unsecured e‑mail, facsimile transmission or other similar unsecured electronic methods. In the absence of gross negligence or willful misconduct, the Trustee's understanding of any such instructions or directions as may be given by the Company pursuant to this paragraph shall be deemed controlling.  The Trustee shall not be liable for any losses, costs or expenses arising directly or indirectly from the Trustee's reliance upon and compliance with such instructions or directions notwithstanding that such instructions or directions conflict or are inconsistent with a subsequent written instruction or direction received by the Trustee after it has acted in compliance with the prior unsecured e-mail, facsimile transmission, or direction or instruction provided by other similar unsecured electronic methods. The Company providing electronic instructions or directions agrees to assume all risks arising out of the use of such electronic methods to submit instructions and directions to the Trustee, including without limitation the risk of the Trustee acting on unauthorized instructions or directions, and the risk of interception and misuse of such electronic instructions or directions by third parties.

(b)WAIVER OF JURY TRIAL.EACH OF THE COMPANY AND THE TRUSTEE HEREBY IRREVOCABLY WAIVES, TO THE FULLEST EXTENT PERMITTED BY APPLICABLE LAW, ANY AND ALL RIGHT TO TRIAL BY JURY IN ANY LEGAL PROCEEDING ARISING OUT OF OR RELATING TO THE INDENTURE, THE SECURITIES OR THE TRANSACTION CONTEMPLATED THEREBY.

(c)Consequential Damages; Uncontrollable Circumstances. As between the parties hereto, (i) in no event shall the Trustee be responsible or liable for consequential loss or damage of any kind whatsoever (including, but not limited to, loss of profit) irrespective of whether the Trustee has been advised of the likelihood of such loss or damage and regardless of the form of proceeding brought against the Trustee; and (ii) in no event shall the Trustee be responsible or liable for any failure or delay in the performance of its obligations hereunder arising out of or caused by, directly or indirectly, forces beyond its control, including, without limitation, strikes, work stoppages, accidents, acts of war or terrorism, civil or military disturbances, nuclear or natural catastrophes or acts of God, and interruptions, loss or malfunctions of utilities, communications or computer (software and hardware) services; it being understood that the Trustee shall use reasonable efforts which are consistent with accepted practices in the banking industry to (a) resume performance as soon as practicable under the circumstances; and (b) maintain its computer (hardware and software) services in good working order.

ARTICLE III

MISCELLANEOUS

Section 3.1Governing Law. This First Supplemental Indenture shall be governed by and construed in accordance with the laws of the State of New York, without regard to conflict of laws principles thereunder, except to the extent that the law of any other jurisdiction shall be mandatorily applicable.

Section 3.2Multiple Originals. The parties hereto may sign any number of copies of this First Supplemental Indenture. Each signed copy shall be an original, but all of them shall represent the same agreement.

Section 3.3Headings. The headings of the Articles and Sections of this First Supplemental Indenture have been inserted for convenience of reference only, are not intended to be considered a part hereof and shall not modify or restrict any of the terms or provisions hereof.

IN WITNESS WHEREOF, the parties hereto have caused this First Supplemental Indenture to be duly executed as of the date first written above.

NextEra Energy Capital Holdings, Inc.,
as Issuer
By:	/s/ Aldo Portales
	Name: Aldo Portales
	Title: Assistant Treasurer
The Bank of New York Mellon,
	as Trustee
By:	/s/ Laurence J. O'Brien
	Name: Laurence J. O'Brien
	Title: Vice President

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) 

	Nine Months Ended September 30, 2012
	(millions of dollars)
Earnings, as defined:
Net income	$	1,482
Income taxes	553
Fixed charges included in the determination of net income, as below	855
Amortization of capitalized interest	18
Distributed income of equity method investees	20
Less:  Equity in earnings of equity method investees	17
Total earnings, as defined	$	2,911
Fixed charges, as defined:
Interest expense	$	795
Rental interest factor	36
Allowance for borrowed funds used during construction	24
Fixed charges included in the determination of net income	855
Capitalized interest	102
Total fixed charges, as defined	$	957
Ratio of earnings to fixed charges and ratio of earnings to combined fixed charges and preferred stock dividends(a)	3.04

————————————

(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) 

	Nine Months Ended September 30, 2012
	(millions of dollars)
Earnings, as defined:
Net income	$	984
Income taxes	600
Fixed charges included in the determination of net income, as below	338
Total earnings, as defined	$	1,922
Fixed charges, as defined:
Interest expense	$	314
Rental interest factor	8
Allowance for borrowed funds used during construction	16
Total fixed charges, as defined	$	338
Ratio of earnings to fixed charges and ratio of earnings to combined fixed charges and preferred stock dividends(a)	5.69

————————————

(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 September 30, 2012 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: October 25, 2012

JAMES L. ROBO

James L. Robo

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 September 30, 2012 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: October 25, 2012

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 September 30, 2012 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: October 25, 2012

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 September 30, 2012 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: October 25, 2012

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 September 30, 2012 (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: October 25, 2012

JAMES L. ROBO

James L. Robo

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 September 30, 2012 (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: October 25, 2012

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 Nonrecurring Fair Value Measurements (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011 MW	Sep. 30, 2012	Sep. 30, 2011 MW
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Carrying value of property, plant, and equipment prior to impairment charge		$ 79		$ 79
Property, Plant, and Equipment, Fair Value Disclosure		28		28
Impairment of Long-Lived Assets Held-for-use	0	0	0	51
Impairment Of Long Lived Assets Held For Use After Tax				31
Megawatts associated with natural gas plants held for sale		2,152		2,152
Disposal Group, Not Discontinued Operation, Loss (Gain) on Write-down	0	148	0	148
Loss on assets held for sale, after-tax		97		97
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net		(21)		(21)
Assets Held For Sale, Income Statement Location [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net		$ (30)		$ (30)

XML

Commitments and Contingencies, Insurance and Legal Proceedings (Details) (USD $)	9 Months Ended	24 Months Ended
	Sep. 30, 2012	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	12,200,000,000
Potential amount of retrospective assessment under secondary financial protection system	940,000,000
Potential amount of retrospective assessment under secondary financial protection system payable per incident per year	140,000,000
Amount of coverage per occurrence per site for property damage, decontamination and premature decommissioning risks	2,750,000,000
Potential amount of retrospective assessment per occurrence per site for property damage, decontamination and premature decommissioning risks	178,000,000
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	14,000,000
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	35,000,000
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	4,000,000
St Lucie Unit No 2 Insurance [Member]
Insurance [Abstract]
Potential retrospective assessment recoverable from minority interest for nuclear liability secondary financial protection	18,000,000
Potential retrospective assessment recoverable from minority interest for property damage, decontamination and premature decommissioning risks	4,000,000
FPL [Member]
Insurance [Abstract]
Potential amount of retrospective assessment under secondary financial protection system	470,000,000
Potential amount of retrospective assessment under secondary financial protection system payable per incident per year	70,000,000
Potential amount of retrospective assessment per occurrence per site for property damage, decontamination and premature decommissioning risks	$ 102,000,000

XML

Commitments and Contingencies, Planned Capital Expenditures (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2012 MW
FPL [Member]
Planned Capital Expenditures [Line Items]
2012	$ 1,020
2013	2,420
2014	2,440
2015	1,830
2016	1,595
Total	9,305
FPL [Member] | New Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
2012	500	[1],[2],[3]
2013	770	[1],[2],[3]
2014	770	[1],[2],[3]
2015	295	[1],[2],[3]
2016	120	[1],[2],[3]
Total	2,455	[1],[2],[3]
Pre-construction costs and carrying charges (equal to a pretax AFUDC rate) - 2012	24
Pre-construction costs and carrying charges (equal to a pretax AFUDC rate) - 2013	42
Pre-construction costs and carrying charges (equal to a pretax AFUDC rate) - 2014	12
FPL [Member] | Existing Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
2012	190	[1]
2013	645	[1]
2014	655	[1]
2015	550	[1]
2016	440	[1]
Total	2,480	[1]
FPL [Member] | Transmission And Distribution Expenditures [Member]
Planned Capital Expenditures [Line Items]
2012	215
2013	690
2014	690
2015	660
2016	705
Total	2,960
FPL [Member] | Nuclear Fuel Expenditures [Member]
Planned Capital Expenditures [Line Items]
2012	70
2013	125
2014	205
2015	245
2016	245
Total	890
FPL [Member] | General And Other Expenditures [Member]
Planned Capital Expenditures [Line Items]
2012	45
2013	190
2014	120
2015	80
2016	85
Total	520
FPL [Member] | Generation Expenditures [Member]
Planned Capital Expenditures [Line Items]
Allowance for funds used during construction (AFUDC) - 2012	24
Allowance for funds used during construction (AFUDC) - 2013	82
Allowance for funds used during construction (AFUDC) - 2014	53
Allowance for funds used during construction (AFUDC) - 2015	48
Allowance for funds used during construction (AFUDC) - 2016	27
NextEra Energy Resources [Member]
Planned Capital Expenditures [Line Items]
2012	1,310
2013	1,470
2014	585
2015	430
2016	390
Total	4,185
NextEra Energy Resources [Member] | Nuclear Fuel Expenditures [Member]
Planned Capital Expenditures [Line Items]
2012	95	[4]
2013	315	[4]
2014	280	[4]
2015	285	[4]
2016	325	[4]
Total	1,300	[4]
NextEra Energy Resources [Member] | Wind Expenditures [Member]
Planned Capital Expenditures [Line Items]
2012	740	[5]
2013	285	[5]
2014	25	[5]
2015	5	[5]
2016	5	[5]
Total	1,060	[5]
Planned New Wind Generation To Be Added over 5 Years	1,500
Planned New Canadian Wind With Internal Approvals	150
Planned New Canadian Wind Generation Requiring Internal Approvals MW	470
Expected Cost of New Wind Projects Requiring Internal Approvals - Low End of Range	1,300
Expected Costs of New Wind Projects Requiring Internal Approvals - High End of Range	1,500
NextEra Energy Resources [Member] | Solar Expenditures [Member]
Planned Capital Expenditures [Line Items]
2012	390	[6]
2013	670	[6]
2014	160	[6]
2015	5	[6]
2016	0	[6]
Total	1,225	[6]
Planned new solar generation over 5 year period (in megawatts)	625
Planned New Solar Capacity of Equity Method Investment	550
Planned new solar capacity of projects requiring internal approvals	270
Expected cost of new solar projects requiring internal approals - Low End of Range	600
Expected Costs of New Solar Projects Requiring Internal Approval - High End of Range	800
NextEra Energy Resources [Member] | Other Expenditures [Member]
Planned Capital Expenditures [Line Items]
2012	85	[7]
2013	200	[7]
2014	120	[7]
2015	135	[7]
2016	60	[7]
Total	600	[7]
Corporate and Other [Member]
Planned Capital Expenditures [Line Items]
2012	115	[8]
2013	115	[8]
2014	45	[8]
2015	45	[8]
2016	45	[8]
Total	365	[8]
Allowance for funds used during construction (AFUDC) - 2012	9
Allowance for funds used during construction (AFUDC) - 2013	$ 14

[1] Includes allowance for funds used during construction (AFUDC) of approximately $24 million, $82 million, $53 million, $48 million and $27 million in 2012 to 2016, respectively.

[2] Consists of projects that have received FPSC approval. Includes pre-construction costs and carrying charges (equal to a pretax AFUDC rate) on construction costs recoverable through the capacity clause of approximately $24 million, $42 million and $12 million in 2012 to 2014, respectively. 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.

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

[4] Includes nuclear fuel.

[5] Consists of capital expenditures for planned new wind projects and related transmission totaling approximately 1,500 mw, including approximately 150 mw in Canada, that have received applicable internal approvals. Excludes new Canadian wind projects requiring internal approvals with generation totaling approximately 470 mw in 2014 and 2015, with an estimated cost of approximately $1.3 billion to $1.5 billion.

[6] Consists of capital expenditures for planned new solar projects and related transmission totaling 625 mw that have received applicable internal approvals, including equity contributions associated with a 50% equity method investment in a 550 mw solar project. Excludes solar projects requiring internal approvals with generation totaling 270 mw with an estimated cost of approximately $600 million to $800 million.

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

[8] Consists of capital expenditures that have received applicable internal approvals and includes AFUDC of approximately $9 million and $14 million in 2012 and 2013, respectively.

XML

Derivative Instruments (Income Statement Disclosure) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2012		Sep. 30, 2011		Sep. 30, 2012		Sep. 30, 2011
Derivative [Line Items]
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net			$ (21)				$ (21)
Effect of Cash Flow Hedges on Results of Operations [Abstract]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	(45)		(250)		(120)		(373)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	(10)		(5)	[1]	(42)		(33)	[1]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(213)		(33)		125		(31)
Gains (losses) on commodity contracts, recorded as regulatory assets and or liabilities on the balance sheet due to regulatory treatment	90		(232)		(86)		(300)
Assets Held For Sale, Income Statement Location [Member]
Derivative [Line Items]
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net			(30)				(30)
Gains (losses) included in Other - net [Member]
Derivative [Line Items]
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net			9				9
Commodity contracts [Member]
Effect of Cash Flow Hedges on Results of Operations [Abstract]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	0		0		0		0
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	2		11		6		30
Commodity contracts [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	(218)		(50)		102		(48)
Commodity contracts [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)		10		36		8
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	(39)		(236)		(104)		(353)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	(14)		(21)		(44)		(64)
Interest Rate 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	0		(16)		0		(11)
Foreign currency swaps [Member]
Effect of Cash Flow Hedges on Results of Operations [Abstract]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	(6)		(14)		(16)		(20)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	2	[2]	5	[2]	(4)	[3]	1	[4]
Foreign currency swaps [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	9		23		(13)		20
Fair Value Hedging [Member]
Gain (Loss) on Fair Value Hedge Ineffectiveness, Net [Abstract]
Gain (Loss) on Fair Value Hedge Ineffectiveness, Net	6		16		41		19
Number of instruments held	6		6		6		6
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)		$ (2)		$ (4)

[1] Included in operating revenues for commodity contracts and interest expense for interest rate swaps. In 2011, excludes approximately $21 million of net losses related to discontinuance of certain cash flow hedges. See further discussion above.

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

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

[4] Loss of approximately $4 million is included in interest expense and the balance is included in other - net.

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Common Stock (Tables)

9 Months Ended

Sep. 30, 2012

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 is as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
	(millions, except per share amounts)
Numerator - net income	$	415	$	407	$	1,482	$	1,256
Denominator:
Weighted-average number of common shares outstanding - basic	419.3		417.4		415.6		416.7
Performance share awards, options, restricted stock and equity units(a)	2.4		2.4		2.4		2.4
Weighted-average number of common shares outstanding - assuming dilution	421.7		419.8		418.0		419.1
Earnings per share of common stock:
Basic	$	0.99	$	0.98	$	3.57	$	3.01
Assuming dilution	$	0.98	$	0.97	$	3.55	$	3.00

————————————

(a) 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.  Performance share awards, options, restricted stock and equity units are included in diluted weighted-average number of common shares outstanding by applying the treasury stock method.

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Summarized Financial Information of Capital Holdings (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2011
Condensed Financial Statements, Captions [Line Items]
FPL Group Capital ownership percentage	100.00%		100.00%
Condensed Consolidating Statements of Income
Operating revenues	$ 3,843	$ 4,382	$ 10,881	$ 11,476
Operating expenses	(3,094)	(3,471)	(8,266)	(9,230)
Interest expense	(259)	(265)	(795)	(775)
Equity in earnings of subsidiaries	0	0	0	0
Other income (deductions) - net	79	(81)	215	58
Income (loss) before income taxes	569	565	2,035	1,529
Income tax expense (benefit)	154	158	553	273
Net income (loss)	415	407	1,482	1,256
Comprehensive income (loss) of NextEra Energy	386	178	1,417	976
PROPERTY, PLANT AND EQUIPMENT
Electric utility plant in service and other property	63,430		63,430		57,552
Less accumulated depreciation and amortization	(15,737)		(15,737)		(15,062)
Total property, plant and equipment - net	47,693		47,693		42,490
CURRENT ASSETS
Cash and cash equivalents	246	640	246	640
Receivables	2,122		2,122		1,802
Other	2,069		2,069		2,693
Total current assets	4,437		4,437		4,872
OTHER ASSETS
Investment in subsidiaries	0		0		0
Other	9,919		9,919		9,826
Total other assets	9,919		9,919		9,826
TOTAL ASSETS	62,049		62,049		57,188
CAPITALIZATION
Common shareholders' equity	15,886		15,886		14,943
Long-term debt	22,714		22,714		20,810
Total capitalization	38,600		38,600		35,753
CURRENT LIABILITIES
Debt due within one year	3,636		3,636		2,157
Accounts payable	1,194		1,194		1,191
Other	3,045		3,045		3,371
Total current liabilities	7,875		7,875		6,719
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,685		1,685		1,611
Accumulated deferred income taxes	6,166		6,166		5,681
Other	7,723		7,723		7,424
Total other liabilities and deferred credits	15,574		15,574		14,716
Commitments and Contingencies
TOTAL CAPITALIZATION AND LIABILITIES	62,049		62,049		57,188
Condensed Consolidating Statements of Cash Flows
NET CASH PROVIDED BY OPERATING ACTIVITIES			3,157	3,117
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases			(6,689)	(4,317)
Capital contribution to FPL			0	0
Cash grants under the Recovery Act			105	503
Change in loan proceeds restricted for construction			212	(596)
Other - net			(129)	(12)
Net cash used in investing activities			(6,501)	(4,422)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt			4,226	2,917
Retirements of long-term debt			(1,321)	(1,688)
Proceeds from sale of differential membership interests			414	210
Net change in short-term debt			396	946
Proceeds from Issuance of Common Stock			386	39
Dividends on common stock			(752)	(689)
Other - net			(64)	(92)
Other Financing Activities, Not Otherwise Separately Disclosed			(136)
Net cash provided by (used in) financing activities			3,213	1,643
Net increase (decrease) in cash and cash equivalents			(131)	338
Cash and cash equivalents at beginning of period			377	302
Cash and cash equivalents at end of period	246	640	246	640
NextEra Energy (Guarantor) [Member]
Condensed Consolidating Statements of Income
Operating revenues	0	0	0	0
Operating expenses	(5)	(4)	(13)	(11)
Interest expense	(2)	(3)	(8)	(10)
Equity in earnings of subsidiaries	416	416	1,480	1,214
Other income (deductions) - net	4	1	5	1
Income (loss) before income taxes	413	410	1,464	1,194
Income tax expense (benefit)	(2)	3	(18)	(62)
Net income (loss)	415	407	1,482	1,256
Comprehensive income (loss) of NextEra Energy	386	178	1,417	976
PROPERTY, PLANT AND EQUIPMENT
Electric utility plant in service and other property	31		31		31
Less accumulated depreciation and amortization	(6)		(6)		(3)
Total property, plant and equipment - net	25		25		28
CURRENT ASSETS
Cash and cash equivalents	1	0	1	0
Receivables	112		112		84
Other	5		5		5
Total current assets	118		118		90
OTHER ASSETS
Investment in subsidiaries	15,858		15,858		14,879
Other	745		745		513
Total other assets	16,603		16,603		15,392
TOTAL ASSETS	16,746		16,746		15,510
CAPITALIZATION
Common shareholders' equity	15,886		15,886		14,943
Long-term debt	0		0		0
Total capitalization	15,886		15,886		14,943
CURRENT LIABILITIES
Debt due within one year	0		0		0
Accounts payable	0		0		0
Other	289		289		250
Total current liabilities	289		289		250
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	0		0		0
Accumulated deferred income taxes	67		67		68
Other	504		504		249
Total other liabilities and deferred credits	571		571		317
Commitments and Contingencies
TOTAL CAPITALIZATION AND LIABILITIES	16,746		16,746		15,510
Condensed Consolidating Statements of Cash Flows
NET CASH PROVIDED BY OPERATING ACTIVITIES			662	979
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases			0	(16)
Capital contribution to FPL			(240)	(310)
Cash grants under the Recovery Act			0	0
Change in loan proceeds restricted for construction			0	0
Other - net			0	16
Net cash used in investing activities			(240)	(310)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt			0	0
Retirements of long-term debt			0	0
Proceeds from sale of differential membership interests			0	0
Net change in short-term debt			0	0
Proceeds from Issuance of Common Stock			386	39
Dividends on common stock			(752)	(689)
Other - net			(56)	(19)
Net cash provided by (used in) financing activities			(422)	(669)
Net increase (decrease) in cash and cash equivalents			0	0
Cash and cash equivalents at beginning of period			1	0
Cash and cash equivalents at end of period	1	0	1	0
Capital Holdings Consolidated [Member]
Condensed Consolidating Statements of Income
Operating revenues	871	1,232	3,112	3,285
Operating expenses	(836)	(973)	(2,346)	(2,662)
Interest expense	(155)	(164)	(479)	(486)
Equity in earnings of subsidiaries	0	0	0	0
Other income (deductions) - net	61	(86)	180	40
Income (loss) before income taxes	(59)	9	467	177
Income tax expense (benefit)	(82)	(60)	(29)	(185)
Net income (loss)	23	69	496	362
Comprehensive income (loss) of NextEra Energy	(6)	(160)	437	76
PROPERTY, PLANT AND EQUIPMENT
Electric utility plant in service and other property	25,778		25,778		22,351
Less accumulated depreciation and amortization	(4,817)		(4,817)		(4,143)
Total property, plant and equipment - net	20,961		20,961		18,208
CURRENT ASSETS
Cash and cash equivalents	226	610	226	610
Receivables	1,090		1,090		1,026
Other	1,003		1,003		1,075
Total current assets	2,319		2,319		2,440
OTHER ASSETS
Investment in subsidiaries	0		0		0
Other	4,783		4,783		4,849
Total other assets	4,783		4,783		4,849
TOTAL ASSETS	28,063		28,063		25,497
CAPITALIZATION
Common shareholders' equity	3,784		3,784		4,030
Long-term debt	15,082		15,082		13,327
Total capitalization	18,866		18,866		17,357
CURRENT LIABILITIES
Debt due within one year	2,712		2,712		1,778
Accounts payable	522		522		512
Other	1,410		1,410		1,520
Total current liabilities	4,644		4,644		3,810
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	495		495		466
Accumulated deferred income taxes	1,273		1,273		1,376
Other	2,785		2,785		2,488
Total other liabilities and deferred credits	4,553		4,553		4,330
Commitments and Contingencies
TOTAL CAPITALIZATION AND LIABILITIES	28,063		28,063		25,497
Condensed Consolidating Statements of Cash Flows
NET CASH PROVIDED BY OPERATING ACTIVITIES			878	1,071
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases			(3,492)	(1,950)
Capital contribution to FPL			0	0
Cash grants under the Recovery Act			105	301
Change in loan proceeds restricted for construction			212	(596)
Other - net			(59)	4
Net cash used in investing activities			(3,234)	(2,241)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt			3,632	2,669
Retirements of long-term debt			(1,272)	(1,643)
Proceeds from sale of differential membership interests			414	210
Net change in short-term debt			254	639
Proceeds from Issuance of Common Stock			0	0
Dividends on common stock			0	0
Other - net			(785)	(377)
Net cash provided by (used in) financing activities			2,243	1,498
Net increase (decrease) in cash and cash equivalents			(113)	328
Cash and cash equivalents at beginning of period			339	282
Cash and cash equivalents at end of period	226	610	226	610
Other Consolidated Entity And Consolidation Eliminations [Member]
Condensed Consolidating Statements of Income
Operating revenues	2,972	3,150	7,769	8,191
Operating expenses	(2,253)	(2,494)	(5,907)	(6,557)
Interest expense	(102)	(98)	(308)	(279)
Equity in earnings of subsidiaries	(416)	(416)	(1,480)	(1,214)
Other income (deductions) - net	14	4	30	17
Income (loss) before income taxes	215	146	104	158
Income tax expense (benefit)	238	215	600	520
Net income (loss)	(23)	(69)	(496)	(362)
Comprehensive income (loss) of NextEra Energy	6	160	(437)	(76)
PROPERTY, PLANT AND EQUIPMENT
Electric utility plant in service and other property	37,621		37,621		35,170
Less accumulated depreciation and amortization	(10,914)		(10,914)		(10,916)
Total property, plant and equipment - net	26,707		26,707		24,254
CURRENT ASSETS
Cash and cash equivalents	19	30	19	30
Receivables	920		920		692
Other	1,061		1,061		1,613
Total current assets	2,000		2,000		2,342
OTHER ASSETS
Investment in subsidiaries	(15,858)		(15,858)		(14,879)
Other	4,391		4,391		4,464
Total other assets	(11,467)		(11,467)		(10,415)
TOTAL ASSETS	17,240		17,240		16,181
CAPITALIZATION
Common shareholders' equity	(3,784)		(3,784)		(4,030)
Long-term debt	7,632		7,632		7,483
Total capitalization	3,848		3,848		3,453
CURRENT LIABILITIES
Debt due within one year	924		924		379
Accounts payable	672		672		679
Other	1,346		1,346		1,601
Total current liabilities	2,942		2,942		2,659
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,190		1,190		1,145
Accumulated deferred income taxes	4,826		4,826		4,237
Other	4,434		4,434		4,687
Total other liabilities and deferred credits	10,450		10,450		10,069
Commitments and Contingencies
TOTAL CAPITALIZATION AND LIABILITIES	17,240		17,240		16,181
Condensed Consolidating Statements of Cash Flows
NET CASH PROVIDED BY OPERATING ACTIVITIES			1,617	1,067
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases			(3,197)	(2,351)
Capital contribution to FPL			240	310
Cash grants under the Recovery Act			0	202
Change in loan proceeds restricted for construction			0	0
Other - net			(70)	(32)
Net cash used in investing activities			(3,027)	(1,871)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt			594	248
Retirements of long-term debt			(49)	(45)
Proceeds from sale of differential membership interests			0	0
Net change in short-term debt			142	307
Proceeds from Issuance of Common Stock			0	0
Dividends on common stock			0	0
Other - net			705	304
Net cash provided by (used in) financing activities			1,392	814
Net increase (decrease) in cash and cash equivalents			(18)	10
Cash and cash equivalents at beginning of period			37	20
Cash and cash equivalents at end of period	$ 19	$ 30	$ 19	$ 30

XML

Income Taxes (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Income Tax Disclosure [Abstract]
Effective income tax rate (as a percent)	27.00%	28.00%	27.00%	18.00%
Production tax credits	$ 35	$ 45	$ 147	$ 208
Deferred income tax benefit associated with convertible investment tax credits	14	9	37	17
Deferred state tax benefit related to recent state tax law changes				64
Consolidated effect of reversal of valuation allowance related to certain state investment tax credits				$ 26

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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	9 Months Ended
	Sep. 30, 2012
Forward Contracts - Power [Member] | Discounted Cash Flow Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets	$ 366
Liabilities	95
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)	$ 10
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)	$ 141
Option Contracts - Power [Member] | Options Models [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets	179
Liabilities	200
Option Contracts - Power [Member] | Options Models [Member] | Implied Correlations [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	12.00%
Option Contracts - Power [Member] | Options Models [Member] | Implied Correlations [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	98.00%
Option Contracts - Power [Member] | Options Models [Member] | Implied Volatilities [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	1.00%
Option Contracts - Power [Member] | Options Models [Member] | Implied Volatilities [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	154.00%
Option Contracts - Gas [Member] | Options Models [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets	43
Liabilities	10
Option Contracts - Gas [Member] | Options Models [Member] | Implied Correlations [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	12.00%
Option Contracts - Gas [Member] | Options Models [Member] | Implied Correlations [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	98.00%
Option Contracts - Gas [Member] | Options Models [Member] | Implied Volatilities [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	1.00%
Option Contracts - Gas [Member] | Options Models [Member] | Implied Volatilities [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Expected rates (as a percentage)	56.00%
Full Requirements and Unit Contingent Contracts [Member] | Discounted Cash Flow Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Assets	211
Liabilities	$ 33
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)	$ 5
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)	$ 127
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%
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%

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Commitments and Contingencies, Long-term Purchase Commitment (Details) (USD $)	3 Months Ended			9 Months Ended
	Sep. 30, 2012		Sep. 30, 2011	Sep. 30, 2012		Sep. 30, 2011
FPL [Member]
Required capacity and/or minimum payments [Abstract]
Capacity payments	$ 129,000,000		$ 128,000,000	$ 391,000,000		$ 383,000,000
Energy payments	110,000,000		135,000,000	232,000,000		348,000,000
FPL [Member] | Jea And Southern Subsidiaries Contract Range 1 [Member]
Long-term Commitment (Excluding Unconditional Purchase Obligation) [Abstract]
Minimum annual purchase commitments (in megawatts)				1,330
Time period under contracts				through 2015
FPL [Member] | Jea And Southern Subsidiaries Contract Range 2 [Member]
Long-term Commitment (Excluding Unconditional Purchase Obligation) [Abstract]
Minimum annual purchase commitments (in megawatts)				375
Time period under contracts				through 2021
FPL [Member] | Qualifying Facilities Contracts [Member]
Long-term Commitment (Excluding Unconditional Purchase Obligation) [Abstract]
Minimum total purchase commitments (in megawatts)				705
Expiration dates of purchase commitments				2024 through 2034
FPL [Member] | Natural Gas, Coal, And Oil, Including Transportation And Storage [Member]
Long-term Commitment (Excluding Unconditional Purchase Obligation) [Abstract]
Expiration dates of purchase commitments				through 2036
FPL [Member] | Qualifying Facilities Capacity Payments [Member]
Required capacity and/or minimum payments [Abstract]
2012	75,000,000	[1]		75,000,000	[1]
2013	270,000,000	[1]		270,000,000	[1]
2014	275,000,000	[1]		275,000,000	[1]
2015	280,000,000	[1]		280,000,000	[1]
2016	245,000,000	[1]		245,000,000	[1]
Thereafter	2,415,000,000	[1]		2,415,000,000	[1]
FPL [Member] | Jea And Southern Subsidiaries Capacity Payments [Member]
Required capacity and/or minimum payments [Abstract]
2012	60,000,000	[1]		60,000,000	[1]
2013	230,000,000	[1]		230,000,000	[1]
2014	220,000,000	[1]		220,000,000	[1]
2015	195,000,000	[1]		195,000,000	[1]
2016	70,000,000	[1]		70,000,000	[1]
Thereafter	155,000,000	[1]		155,000,000	[1]
FPL [Member] | Natural Gas, Including Transportation And Storage, Contract Minimum Payments [Member]
Required capacity and/or minimum payments [Abstract]
2012	495,000,000	[2]		495,000,000	[2]
2013	1,580,000,000	[2]		1,580,000,000	[2]
2014	1,065,000,000	[2]		1,065,000,000	[2]
2015	570,000,000	[2]		570,000,000	[2]
2016	535,000,000	[2]		535,000,000	[2]
Thereafter	6,935,000,000	[2]		6,935,000,000	[2]
FPL [Member] | Coal Contract Minimum Payments [Member]
Required capacity and/or minimum payments [Abstract]
2012	25,000,000	[2]		25,000,000	[2]
2013	90,000,000	[2]		90,000,000	[2]
2014	35,000,000	[2]		35,000,000	[2]
2015	5,000,000	[2]		5,000,000	[2]
2016	5,000,000	[2]		5,000,000	[2]
Thereafter	0	[2]		0	[2]
NextEra Energy Resources [Member]
Required capacity and/or minimum payments [Abstract]
2012	610,000,000			610,000,000
2013	690,000,000			690,000,000
2014	235,000,000			235,000,000
2015	85,000,000			85,000,000
2016	105,000,000			105,000,000
Thereafter	600,000,000			600,000,000
NextEra Energy Resources [Member] | Contract Group 1 [Member]
Long-term Commitment (Excluding Unconditional Purchase Obligation) [Abstract]
Expiration dates of purchase commitments				December 2012 through 2030
Commitment amount included in capital expenditures	1,700,000,000			1,700,000,000
NextEra Energy Resources [Member] | Contract Group 2 [Member]
Long-term Commitment (Excluding Unconditional Purchase Obligation) [Abstract]
Expiration dates of purchase commitments				December 2012 through 2033
Corporate and Other [Member]
Required capacity and/or minimum payments [Abstract]
2012	65,000,000	[3]		65,000,000	[3]
2013	30,000,000	[3]		30,000,000	[3]
2014	10,000,000	[3]		10,000,000	[3]
2015	15,000,000	[3]		15,000,000	[3]
2016	15,000,000	[3]		15,000,000	[3]
Thereafter	20,000,000	[3]		20,000,000	[3]
Commitment to invest	$ 68,000,000			$ 68,000,000

[1] Capacity charges under these contracts, substantially all of which are recoverable through the capacity clause, totaled approximately $129 million and $128 million for the three months ended September 30, 2012 and 2011, respectively, and approximately $391 million and $383 million for the nine months ended September 30, 2012 and 2011, respectively. Energy charges under these contracts, which are recoverable through the fuel clause, totaled approximately $110 million and $135 million for the three months ended September 30, 2012 and 2011, respectively

[2] Recoverable through the fuel clause.

[3] Includes an approximately $68 million commitment to invest in clean power and technology businesses through 2017.

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Derivative Instruments

9 Months Ended

Sep. 30, 2012

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments

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 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 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 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 energy output of these assets.  These hedges protect NEER against adverse changes in the wholesale forward commodity markets associated with its generation 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 customer served by the distribution utility.  For this type of transaction, derivative instruments are used to hedge the anticipated electricity quantities required to serve these customers and protect against 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.  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) or the capacity cost recovery clause (capacity clause).  For NEE's non-rate regulated operations, predominantly NEER, unless hedge accounting is applied, essentially all changes in the derivatives' fair value for power purchases and sales and trading activities are recognized on a net basis in operating revenues; fuel purchases and sales are recognized on a net basis in fuel, purchased power and interchange expense; and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's 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.  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.  Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the condensed consolidated statements of income.  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, 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 swaps 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. At September 30, 2012, NEE's accumulated other comprehensive income (AOCI) included amounts related to discontinued commodity cash flow hedges with expiration dates through December 2012; interest rate cash flow hedges with expiration dates through December 2030; and foreign currency cash flow hedges with expiration dates through September 2030. Approximately $39 million of net losses included in AOCI at September 30, 2012 is expected to be reclassified into earnings within the next 12 months as either the principal and/or interest payments are made or electricity is sold. Such amounts assume no change in power prices, interest rates, currency exchange rates or scheduled principal payments.

In the third quarter of 2011, a subsidiary of NEER entered into an agreement to sell its ownership interest in four natural gas-fired generating plants. See Note 3 - Nonrecurring Fair Value Measurements. Certain of the plants had hedged their exposure to interest rate and commodity price fluctuations by entering into derivative contracts. Because the plants were being sold to a third party, it became no longer probable that the future hedged transactions would occur. Therefore, NEE was required to reclassify any gains or losses in AOCI related to those hedges to earnings. During the three and nine months ended September 30, 2011, NEE reclassified approximately $21 million of net losses to earnings, $30 million of losses were recorded in loss on natural gas-fired generating assets held for sale and $9 million of gains were recorded in other - net.

The net fair values of NEE's and FPL's mark-to-market derivative instrument assets (liabilities) are included on the condensed consolidated balance sheets as follows:

	NEE						FPL
	September 30, 2012			December 31, 2011			September 30, 2012				December 31, 2011
	(millions)
Current derivative assets(a)	$	482		$	611		$	8		(b)	$	10		(b)
Noncurrent derivative assets(c)	944			973			32			(d)	2			(d)
Current derivative liabilities(e)	(486		)	(1,090		)	(67		)		(512		)
Noncurrent derivative liabilities(f)	(530		)	(541		)	—				(1		)	(g)
Total mark-to-market derivative instrument assets (liabilities)	$	410		$	(47	)	$	(27	)		$	(501	)

————————————

(a) At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $40 million and $106 million (none at FPL), respectively, in margin cash collateral received from counterparties.

(b) Included in current other assets on FPL's condensed consolidated balance sheets.

(c) At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $154 million and $109 million (none at FPL), respectively, in margin cash collateral received from counterparties.

(d) Included in noncurrent other assets on FPL's condensed consolidated balance sheets.

(e) At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $74 million and $112 million (none at FPL), respectively, in margin cash collateral provided to counterparties.

(f) At December 31, 2011, NEE's balance reflects the netting of approximately $79 million (none at FPL) in margin cash collateral provided to counterparties.

(g) Included in noncurrent other liabilities on FPL's condensed consolidated balance sheets.

At September 30, 2012 and December 31, 2011, NEE had approximately $44 million and $22 million (none at FPL), respectively, in margin cash collateral received from counterparties that was not offset against derivative assets.  These amounts are included in current other liabilities on NEE's condensed consolidated balance sheets.  Additionally, at September 30, 2012 and December 31, 2011, NEE had approximately $54 million and $50 million (none at FPL), respectively, in margin cash collateral provided to counterparties that was not offset against derivative liabilities.  These amounts are included in current other assets on NEE's condensed consolidated balance sheets.

As discussed above, NEE uses derivative instruments to, among other things, manage its commodity price risk, interest rate risk and foreign currency exchange rate risk.  The table above presents NEE's and FPL's net derivative positions at September 30, 2012 and December 31, 2011, 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.  However, disclosure rules require that the following tables be presented on a gross basis.

The fair values of NEE's derivatives designated as hedging instruments for accounting purposes (none at FPL) are presented below as gross asset and liability values, as required by disclosure rules.

	September 30, 2012				December 31, 2011
	Derivative Assets		Derivative Liabilities		Derivative Assets		Derivative Liabilities
	(millions)
Interest rate swaps:
Current derivative assets	$	26	$	—	$	22	$	—
Current derivative liabilities	—		97		—		60
Noncurrent derivative assets	54		—		15		—
Noncurrent derivative liabilities	—		294		—		260
Foreign currency swap:
Current derivative liabilities	—		3		—		3
Noncurrent derivative liabilities	—		5		—		3
Total	$	80	$	399	$	37	$	326

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 September 30,
	2012												2011
	Commodity Contracts		Interest Rate Swaps			Foreign Currency Swap				Total			Commodity Contracts		Interest Rate Swaps			Foreign Currency Swaps				Total
	(millions)
Gains (losses) recognized in OCI	$	—	$	(39	)	$	(6	)		$	(45	)	$	—	$	(236	)	$	(14	)		$	(250	)
Gains (losses) reclassified from AOCI to net income(a)	$	2	$	(14	)	$	2		(b)	$	(10	)	$	11	$	(21	)	$	5		(b)	$	(5	)

————————————

(a) Included in operating revenues for commodity contracts and interest expense for interest rate swaps. In 2011, excludes approximately $21 million of net losses related to discontinuance of certain cash flow hedges. See further discussion above.

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

	Nine Months Ended September 30,
	2012												2011
	Commodity Contracts		Interest Rate Swaps			Foreign Currency Swap				Total			Commodity Contracts		Interest Rate Swaps			Foreign Currency Swaps				Total
	(millions)
Gains (losses) recognized in OCI	$	—	$	(104	)	$	(16	)		$	(120	)	$	—	$	(353	)	$	(20	)		$	(373	)
Gains (losses) reclassified from AOCI to net income(a)	$	6	$	(44	)	$	(4	)	(b)	$	(42	)	$	30	$	(64	)	$	1		(c)	$	(33	)

————————————

(a) Included in operating revenues for commodity contracts and interest expense for interest rate swaps. In 2011, excludes approximately $21 million of net losses related to discontinuance of certain cash flow hedges. See further discussion above.

(b) Loss of approximately $2 million is included in interest expense and the balance is included in other - net.

(c) Loss of approximately $4 million is included in interest expense and the balance is included in other - net.

For the three and nine months ended September 30, 2012, NEE recorded a gain of approximately $6 million and $41 million, respectively, on six fair value hedges which resulted in a corresponding increase in the related debt.  For the three and nine months ended September 30, 2011, NEE recorded a gain of approximately $16 million and $19 million, respectively, on six fair value hedges which resulted in a corresponding increase in the related debt.

The fair values of NEE's and FPL's derivatives not designated as hedging instruments for accounting purposes are presented below as gross asset and liability values, as required by disclosure rules.  However, the majority of the underlying contracts are subject to master netting arrangements and would not be contractually settled on a gross basis.

	September 30, 2012										December 31, 2011
	NEE				FPL						NEE				FPL
	Derivative Assets		Derivative Liabilities		Derivative Assets			Derivative Liabilities			Derivative Assets		Derivative Liabilities		Derivative Assets			Derivative Liabilities
	(millions)
Commodity contracts:
Current derivative assets	$	922	$	426	$	12	(a)	$	4	(a)	$	1,127	$	432	$	11	(a)	$	1	(a)
Current derivative liabilities	1,775		2,233		43			110			3,358		4,494		1			513
Noncurrent derivative assets	1,913		884		32		(b)	—			1,290		250		2		(b)	—
Noncurrent derivative liabilities	233		464		—			—			1,222		1,579		—			1		(c)
Foreign currency swap:
Current derivative liabilities	—		2		—			—			—		3		—			—
Noncurrent derivative assets	15		—		—			—			27		—		—			—
Total	$	4,858	$	4,009	$	87		$	114		$	7,024	$	6,758	$	14		$	515

————————————

(a) Included in current other assets on FPL's condensed consolidated balance sheets.

(b) Included in noncurrent other assets on FPL's condensed consolidated balance sheets.

(c) Included in noncurrent other liabilities on FPL's condensed consolidated balance sheets.

Gains (losses) related to NEE's derivatives not designated as hedging instruments are recorded in NEE's condensed consolidated statements of income (none at FPL) as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(millions)
Commodity contracts(a):
Operating revenues	$	(218	)	$	(50	)	$	102		$	(48	)
Fuel, purchased power and interchange	(4		)	10			36			8
Foreign currency swap - other - net	9			23			(13		)	20
Interest rate contracts - other - net	—			(16		)	—			(11		)
Total	$	(213	)	$	(33	)	$	125		$	(31	)

————————————

(a) For the three months ended September 30, 2012 and 2011, FPL recorded approximately $90 million of gains and $232 million of losses, respectively, related to commodity contracts as regulatory liabilities and regulatory assets, respectively, on its condensed consolidated balance sheets.  For the nine months ended September 30, 2012 and 2011, FPL recorded approximately $86 million and $300 million of losses, respectively, related to commodity contracts as regulatory assets on its condensed consolidated balance sheets.

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.  The table does not present a complete picture of NEE's and FPL's overall net economic exposure because NEE and FPL do not use derivative instruments to hedge all of their commodity exposures.  At September 30, 2012, NEE and FPL had derivative commodity contracts for the following net notional volumes:

Commodity Type	NEE			FPL
	(millions)
Power	(46	)	mwh(a)	—
Natural gas	1,221		mmbtu(b)	837	mmbtu(b)
Oil	(7	)	barrels	—

————————————

(a) Megawatt-hours

(b) One million British thermal units

At September 30, 2012, NEE had interest rate contracts with a notional amount totaling approximately $6.9 billion and foreign currency swaps with a notional amount totaling approximately $544 million.

Certain of NEE's and FPL's 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 September 30, 2012, the aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately $2.2 billion ($115 million for FPL).

If the credit-risk-related contingent features underlying these agreements and other commodity-related contracts were triggered, NEE or 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), NEE would be required to post collateral such that the total posted collateral would be approximately $350 million ($10 million at FPL).If FPL's and NEECH's credit ratings were downgraded to below investment grade, NEE would be required to post additional collateral such that the total posted collateral would be approximately $2.2 billion ($500 million at FPL).  Some contracts at NEE, including some FPL 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, NEE could be required to post additional collateral of up to approximately $600 million ($100 million at FPL).

Collateral may be posted in the form of cash or credit support.  At September 30, 2012, NEE had posted approximately $210 million (none at FPL) in the form of letters of credit, related to derivatives, in the normal course of business which could be applied toward the collateral requirements described above.  FPL and NEECH have credit facilities 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.

XML

Variable Interest Entities (VIEs) (Details) (USD $) In Millions, unless otherwise specified							3 Months Ended		9 Months Ended					9 Months Ended			9 Months Ended
	Sep. 30, 2012	Sep. 30, 2012 Other variable interest entities [Member]	Dec. 31, 2011 Other variable interest entities [Member]	Sep. 30, 2012 FPL [Member] Bankruptcy remote special purpose subsidiary [Member]	Dec. 31, 2011 FPL [Member] Bankruptcy remote special purpose subsidiary [Member]	Dec. 31, 2007 FPL [Member] Bankruptcy remote special purpose subsidiary [Member]	Sep. 30, 2012 FPL [Member] Qualifying facility 1 [Member] MWh	Sep. 30, 2011 FPL [Member] Qualifying facility 1 [Member] MWh	Sep. 30, 2012 FPL [Member] Qualifying facility 1 [Member] MW MWh	Sep. 30, 2011 FPL [Member] Qualifying facility 1 [Member] MWh	Sep. 30, 2012 FPL [Member] Qualifying facility 2 [Member] MW	Sep. 30, 2012 FPL [Member] Other variable interest entities [Member]	Dec. 31, 2011 FPL [Member] Other variable interest entities [Member]	Sep. 30, 2012 NextEra Energy Resources [Member]	Sep. 30, 2012 NextEra Energy Resources [Member] Gas and/or oil variable interest entities [Member] MW entities	Dec. 31, 2011 NextEra Energy Resources [Member] Gas and/or oil variable interest entities [Member]	Sep. 30, 2012 NextEra Energy Resources [Member] Wind variable interest entities [Member] MW	Dec. 31, 2011 NextEra Energy Resources [Member] Wind variable interest entities [Member]
Variable Interest Entity [Line Items]
Total number of consolidated variable interest entities	10													9	1		8	6
Storm-recovery bonds aggregate principal amount issued						$ 652
Proceeds from issuance of storm-recovery bonds						644
Carrying amount of assets, consolidated variable interest entity				356	406										96	105	4,100	3,200
Carrying amount of liabilities, consolidated variable interest entity				441	496										74	82	2,800	2,600
Coal fired generating facility capacity (in megawatts)									250		330
Quantity of electricity purchased (in megawatt-hours)							293,650	327,583	582,661	965,105
Cost of electricity purchased							48	50	133	144
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		2037
Wind electric generating facility capability (in megawatts)																	2,658
Total number of consolidated VIEs sell electric output under power sales contracts																	7
Total number of consolidated VIEs sell in spot market																	1
Investments in special purpose entities		$ 784	$ 668									$ 619	$ 526

XML

Summarized Financial Information of Capital Holdings (Tables)

9 Months Ended

Sep. 30, 2012

Summarized Financial Information [Abstract]

Condensed Consolidating Statements

Condensed consolidating financial information is as follows:

Condensed Consolidating Statements of Income

	Three Months Ended September 30,
	2012												2011
	NEE (Guarantor)			NEECH			Other(a)			NEE Consoli- dated			NEE (Guarantor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
Operating revenues	$	—		$	871		$	2,972		$	3,843		$	—		$	1,232		$	3,150		$	4,382
Operating expenses	(5		)	(836		)	(2,253		)	(3,094		)	(4		)	(973		)	(2,494		)	(3,471		)
Interest expense	(2		)	(155		)	(102		)	(259		)	(3		)	(164		)	(98		)	(265		)
Equity in earnings of subsidiaries	416			—			(416		)	—			416			—			(416		)	—
Other income (deductions) - net	4			61			14			79			1			(86		)	4			(81		)
Income (loss) before income taxes	413			(59		)	215			569			410			9			146			565
Income tax expense (benefit)	(2		)	(82		)	238			154			3			(60		)	215			158
Net income (loss)	$	415		$	23		$	(23	)	$	415		$	407		$	69		$	(69	)	$	407

	Nine Months Ended September 30,
	2012												2011
	NEE(Guarantor)			NEECH			Other(a)			NEE Consoli- dated			NEE(Guarantor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
Operating revenues	$	—		$	3,112		$	7,769		$	10,881		$	—		$	3,285		$	8,191		$	11,476
Operating expenses	(13		)	(2,346		)	(5,907		)	(8,266		)	(11		)	(2,662		)	(6,557		)	(9,230		)
Interest expense	(8		)	(479		)	(308		)	(795		)	(10		)	(486		)	(279		)	(775		)
Equity in earnings of subsidiaries	1,480			—			(1,480		)	—			1,214			—			(1,214		)	—
Other income (deductions) - net	5			180			30			215			1			40			17			58
Income (loss) before income taxes	1,464			467			104			2,035			1,194			177			158			1,529
Income tax expense (benefit)	(18		)	(29		)	600			553			(62		)	(185		)	520			273
Net income (loss)	$	1,482		$	496		$	(496	)	$	1,482		$	1,256		$	362		$	(362	)	$	1,256

————————————

(a)  Represents FPL and consolidating adjustments.

Condensed Consolidating Statements of Comprehensive Income

	Three Months Ended September 30,
	2012									2011
	NEE (Guarantor)		NEECH			Other(a)		NEE Consoli- dated		NEE (Guarantor)		NEECH			Other(a)		NEE Consoli- dated
								(millions)
Comprehensive income (loss)	$	386	$	(6	)	$	6	$	386	$	178	$	(160	)	$	160	$	178

	Nine Months Ended September 30,
	2012									2011
	NEE (Guarantor)		NEECH		Other(a)			NEE Consoli- dated		NEE (Guarantor)		NEECH		Other(a)			NEE Consoli- dated
								(millions)
Comprehensive income (loss)	$	1,417	$	437	$	(437	)	$	1,417	$	976	$	76	$	(76	)	$	976

————————————

(a) Represents FPL and consolidating adjustments.

Condensed Consolidating Balance Sheets

	September 30, 2012												December 31, 2011
	NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated			NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
PROPERTY, PLANT AND EQUIPMENT
Electric utility plant in service and other property	$	31		$	25,778		$	37,621		$	63,430		$	31		$	22,351		$	35,170		$	57,552
Less accumulated depreciation and amortization	(6		)	(4,817		)	(10,914		)	(15,737		)	(3		)	(4,143		)	(10,916		)	(15,062		)
Total property, plant and equipment - net	25			20,961			26,707			47,693			28			18,208			24,254			42,490
CURRENT ASSETS
Cash and cash equivalents	1			226			19			246			1			339			37			377
Receivables	112			1,090			920			2,122			84			1,026			692			1,802
Other	5			1,003			1,061			2,069			5			1,075			1,613			2,693
Total current assets	118			2,319			2,000			4,437			90			2,440			2,342			4,872
OTHER ASSETS
Investment in subsidiaries	15,858			—			(15,858		)	—			14,879			—			(14,879		)	—
Other	745			4,783			4,391			9,919			513			4,849			4,464			9,826
Total other assets	16,603			4,783			(11,467		)	9,919			15,392			4,849			(10,415		)	9,826
TOTAL ASSETS	$	16,746		$	28,063		$	17,240		$	62,049		$	15,510		$	25,497		$	16,181		$	57,188
CAPITALIZATION
Common shareholders' equity	$	15,886		$	3,784		$	(3,784	)	$	15,886		$	14,943		$	4,030		$	(4,030	)	$	14,943
Long-term debt	—			15,082			7,632			22,714			—			13,327			7,483			20,810
Total capitalization	15,886			18,866			3,848			38,600			14,943			17,357			3,453			35,753
CURRENT LIABILITIES
Debt due within one year	—			2,712			924			3,636			—			1,778			379			2,157
Accounts payable	—			522			672			1,194			—			512			679			1,191
Other	289			1,410			1,346			3,045			250			1,520			1,601			3,371
Total current liabilities	289			4,644			2,942			7,875			250			3,810			2,659			6,719
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	—			495			1,190			1,685			—			466			1,145			1,611
Accumulated deferred income taxes	67			1,273			4,826			6,166			68			1,376			4,237			5,681
Other	504			2,785			4,434			7,723			249			2,488			4,687			7,424
Total other liabilities and deferred credits	571			4,553			10,450			15,574			317			4,330			10,069			14,716
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	16,746		$	28,063		$	17,240		$	62,049		$	15,510		$	25,497		$	16,181		$	57,188

————————————

(a) Represents FPL and consolidating adjustments.

Condensed Consolidating Statements of Cash Flows

	Nine Months Ended September 30,
	2012												2011
	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	$	662		$	878		$	1,617		$	3,157		$	979		$	1,071		$	1,067		$	3,117
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	—			(3,492		)	(3,197		)	(6,689		)	(16		)	(1,950		)	(2,351		)	(4,317		)
Capital contribution to FPL	(240		)	—			240			—			(310		)	—			310			—
Cash grants under the Recovery Act	—			105			—			105			—			301			202			503
Change in loan proceeds restricted for construction	—			212			—			212			—			(596		)	—			(596		)
Other - net	—			(59		)	(70		)	(129		)	16			4			(32		)	(12		)
Net cash used in investing activities	(240		)	(3,234		)	(3,027		)	(6,501		)	(310		)	(2,241		)	(1,871		)	(4,422		)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	—			3,632			594			4,226			—			2,669			248			2,917
Retirements of long-term debt	—			(1,272		)	(49		)	(1,321		)	—			(1,643		)	(45		)	(1,688		)
Proceeds from sale of differential membership interests	—			414			—			414			—			210			—			210
Net change in short-term debt	—			254			142			396			—			639			307			946
Issuances of common stock	386			—			—			386			39			—			—			39
Dividends on common stock	(752		)	—			—			(752		)	(689		)	—			—			(689		)
Other - net	(56		)	(785		)	705			(136		)	(19		)	(377		)	304			(92		)
Net cash provided by (used in) financing activities	(422		)	2,243			1,392			3,213			(669		)	1,498			814			1,643
Net increase (decrease) in cash and cash equivalents	—			(113		)	(18		)	(131		)	—			328			10			338
Cash and cash equivalents at beginning of period	1			339			37			377			—			282			20			302
Cash and cash equivalents at end of period	$	1		$	226		$	19		$	246		$	—		$	610		$	30		$	640

————————————

(a) Represents FPL and consolidating adjustments.

XML

Segment Information (Tables)

9 Months Ended

Sep. 30, 2012

Segment Reporting [Abstract]

Segment information

	Three Months Ended September 30,
	2012										2011
	FPL		NEER(a)			Corporate and Other			NEE Consoli- dated		FPL		NEER(a)			Corporate and Other				NEE Consoli- dated
									(millions)
Operating revenues	$	2,975	$	808		$	60		$	3,843	$	3,152	$	1,172		$	58			$	4,382
Operating expenses	$	2,256	$	785		$	53		$	3,094	$	2,496	$	920		$	55			$	3,471
Net income	$	392	$	44	(b)	$	(21	)	$	415	$	347	$	67	(b)	$	(7	)	(c)	$	407

	Nine Months Ended September 30,
	2012										2011
	FPL		NEER(a)			Corporate and Other			NEE Consoli- dated		FPL		NEER(a)			Corporate and Other			NEE Consoli- dated
									(millions)
Operating revenues	$	7,778	$	2,929		$	174		$	10,881	$	8,200	$	3,110		$	166		$	11,476
Operating expenses	$	5,916	$	2,201		$	149		$	8,266	$	6,566	$	2,520	(d)	$	144		$	9,230
Net income	$	984	$	516	(b)	$	(18	)	$	1,482	$	852	$	371	(b)(e)	$	33	(c)(f)	$	1,256

	September 30, 2012								December 31, 2011
	FPL		NEER		Corporate and Other		NEE Consoli- dated		FPL		NEER		Corporate and Other		NEE Consoli- dated
							(millions)
Total assets	$	34,120	$	25,761	$	2,168	$	62,049	$	31,816	$	23,459	$	1,913	$	57,188

————————————

(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) See Note 5 for a discussion of NEER's tax benefits related to PTCs. 2011 includes after-tax loss on natural gas-fired generating assets held for sale of $91 million.  See Note 3 - Nonrecurring Fair Value Measurements.  

(c) Includes after-tax loss on natural gas-fired generating assets held for sale of $6 million.  See Note 3 - Nonrecurring Fair Value Measurements.

(d) Includes impairment charges of approximately $51 million.  See Note 3 - Nonrecurring Fair Value Measurements.

(e) Includes after-tax impairment charges of approximately $31 million.  See Note 3 - Nonrecurring Fair Value Measurements.

(f) Includes the state deferred income tax benefit of approximately $64 million.  See Note 5.

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Common Stock (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2012		Sep. 30, 2011		Sep. 30, 2012		Sep. 30, 2011
Reconciliation of basic and diluted earnings per share of common stock [Abstract]
Numerator - net income	$ 415		$ 407		$ 1,482		$ 1,256
Denominator:
Weighted-average number of common shares outstanding - basic (in shares)	419.3		417.4		415.6		416.7
Performance share awards, options, restricted stock and equity units (in shares)	2.4	[1]	2.4	[1]	2.4	[1]	2.4	[1]
Weighted-average number of common shares outstanding - assuming dilution (in shares)	421.7		419.8		418.0		419.1
Earnings per share of common stock:
Basic (in dollars per share)	$ 0.99		$ 0.98		$ 3.57		$ 3.01
Assuming dilution (in dollars per share)	$ 0.98		$ 0.97		$ 3.55		$ 3.00
Antidilutive securities (in shares)	3.2		14.6		9.9		14.5

[1] 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. Performance share awards, options, restricted stock and equity units are included in diluted weighted-average number of common shares outstanding by applying the treasury stock method.

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Employee Retirement Benefits (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Pension Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Service cost	$ 16	$ 16	$ 49	$ 48
Interest cost	25	25	74	74
Expected return on plan assets	(60)	(60)	(179)	(179)
Amortization of transition obligation	0	0	0	0
Amortization of prior service cost (benefit)	1	(1)	3	(2)
Net periodic benefit (income) cost	(18)	(20)	(53)	(59)
Other Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Service cost	1	2	4	5
Interest cost	4	5	13	16
Expected return on plan assets	0	(1)	(1)	(2)
Amortization of transition obligation	0	1	1	2
Amortization of prior service cost (benefit)	(1)	0	0	0
Net periodic benefit (income) cost	4	7	17	21
FPL [Member] | Pension Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Net periodic benefit (income) cost	(11)	(13)	(34)	(39)
FPL [Member] | Other Benefits [Member]
Net periodic benefit (income) cost [Abstract]
Net periodic benefit (income) cost	$ 3	$ 5	$ 13	$ 16

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Derivative Instruments (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012		Sep. 30, 2012		Dec. 31, 2011
Net fair values of mark-to-market derivative instrument assets (liabilities) [Abstract]
Current derivative assets	$ 482	[1]	$ 482	[1]	$ 611	[1]
Noncurrent derivative assets	944	[2]	944	[2]	973	[2]
Current derivative liabilities	(486)	[3]	(486)	[3]	(1,090)	[3]
Noncurrent derivative liabilities	(530)	[4]	(530)	[4]	(541)	[4]
Total mark-to-market derivative instrument assets (liabilities)	410		410		(47)
Summary of derivative instruments by risk exposure, maximum maturity [Abstract]
Maximum length of time hedged in commodity cash flow hedges			through December 2012
Maximum length of time hedged in interest rate cash flow hedges			through December 2030
Maximum Length of Time Hedged in Foreign Currency Cash Flow Hedge			through September 2030
Margin cash collateral received from counterparties - netted against current derivative assets	40		40		106
Margin cash collateral received from counterparties - netted against noncurrent derivative assets	154		154		109
Margin cash collateral provided to counterparties - netted against current derivative liabilities	74		74		112
Margin cash collateral provided to counterparties - netted against noncurrent derivative liabilities					79
Margin cash collateral received from counterparties that was not offset against derivative assets	44		44		22
Margin cash collateral provided to counterparties that was not offset against derivative liabilities	54		54		50
Total gain (loss) to be reclassified during next 12 months	(39)
FPL [Member]
Net fair values of mark-to-market derivative instrument assets (liabilities) [Abstract]
Current derivative assets	8	[1],[5]	8	[1],[5]	10	[1],[5]
Noncurrent derivative assets	32	[2],[6]	32	[2],[6]	2	[2],[6]
Current derivative liabilities	(67)	[3]	(67)	[3]	(512)	[3]
Noncurrent derivative liabilities	0	[4],[7]	0	[4],[7]	(1)	[4],[7]
Total mark-to-market derivative instrument assets (liabilities)	$ (27)		$ (27)		$ (501)

[1] At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $40 million and $106 million (none at FPL), respectively, in margin cash collateral received from counterparties.

[2] At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $154 million and $109 million (none at FPL), respectively, in margin cash collateral received from counterparties.

[3] At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $74 million and $112 million (none at FPL), respectively, in margin cash collateral provided to counterparties.

[4] At December 31, 2011, NEE's balance reflects the netting of approximately $79 million (none at FPL) in margin cash collateral provided to counterparties.

[5] Included in current other assets on FPL's condensed consolidated balance sheets.

[6] Included in noncurrent other assets on FPL's condensed consolidated balance sheets.

[7] Included in noncurrent other liabilities on FPL's condensed consolidated balance sheets.

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Employee Retirement Benefits

9 Months Ended

Sep. 30, 2012

Compensation and Retirement Disclosure [Abstract]

Employee Retirement Benefits

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						Pension Benefits						Other Benefits
	Three Months Ended September 30,						Three Months Ended September 30,						Nine Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011			2012			2011			2012			2011
	(millions)
Service cost	$	16		$	16		$	1		$	2		$	49		$	48		$	4		$	5
Interest cost	25			25			4			5			74			74			13			16
Expected return on plan assets	(60		)	(60		)	—			(1		)	(179		)	(179		)	(1		)	(2		)
Amortization of transition obligation	—			—			—			1			—			—			1			2
Amortization of prior service cost (benefit)	1			(1		)	(1		)	—			3			(2		)	—			—
Net periodic benefit (income) cost at NEE	$	(18	)	$	(20	)	$	4		$	7		$	(53	)	$	(59	)	$	17		$	21
Net periodic benefit (income) cost at FPL	$	(11	)	$	(13	)	$	3		$	5		$	(34	)	$	(39	)	$	13		$	16

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Derivative Instruments (Balance Sheet Disclosure) (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012 Not Designated as Hedging Instrument [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member]	Sep. 30, 2012 Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Current derivative assets [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Current derivative assets [Member]	Sep. 30, 2012 Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Current derivative liabilities [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Current derivative liabilities [Member]	Sep. 30, 2012 Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Non Current Other Assets Member	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Non Current Other Assets Member	Sep. 30, 2012 Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Noncurrent derivative liabilities [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Noncurrent derivative liabilities [Member]	Sep. 30, 2012 Not Designated as Hedging Instrument [Member] Foreign currency swaps [Member] Current derivative liabilities [Member]	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Foreign currency swaps [Member] Current derivative liabilities [Member]	Sep. 30, 2012 Not Designated as Hedging Instrument [Member] Foreign currency swaps [Member] Non Current Other Assets Member	Dec. 31, 2011 Not Designated as Hedging Instrument [Member] Foreign currency swaps [Member] Non Current Other Assets Member	Sep. 30, 2012 Derivatives designated as hedging instruments [Member]	Dec. 31, 2011 Derivatives designated as hedging instruments [Member]	Sep. 30, 2012 Derivatives designated as hedging instruments [Member] Interest Rate Contract [Member] Current derivative assets [Member]	Dec. 31, 2011 Derivatives designated as hedging instruments [Member] Interest Rate Contract [Member] Current derivative assets [Member]	Sep. 30, 2012 Derivatives designated as hedging instruments [Member] Interest Rate Contract [Member] Current derivative liabilities [Member]	Dec. 31, 2011 Derivatives designated as hedging instruments [Member] Interest Rate Contract [Member] Current derivative liabilities [Member]	Sep. 30, 2012 Derivatives designated as hedging instruments [Member] Interest Rate Contract [Member] Non Current Other Assets Member	Dec. 31, 2011 Derivatives designated as hedging instruments [Member] Interest Rate Contract [Member] Non Current Other Assets Member	Sep. 30, 2012 Derivatives designated as hedging instruments [Member] Interest Rate Contract [Member] Noncurrent derivative liabilities [Member]	Dec. 31, 2011 Derivatives designated as hedging instruments [Member] Interest Rate Contract [Member] Noncurrent derivative liabilities [Member]	Sep. 30, 2012 Derivatives designated as hedging instruments [Member] Foreign currency swaps [Member] Current derivative liabilities [Member]	Dec. 31, 2011 Derivatives designated as hedging instruments [Member] Foreign currency swaps [Member] Current derivative liabilities [Member]	Sep. 30, 2012 Derivatives designated as hedging instruments [Member] Foreign currency swaps [Member] Noncurrent derivative liabilities [Member]	Dec. 31, 2011 Derivatives designated as hedging instruments [Member] Foreign currency swaps [Member] Noncurrent derivative liabilities [Member]	Sep. 30, 2012 FPL [Member]	Jun. 30, 2011 FPL [Member]	Sep. 30, 2012 FPL [Member] Not Designated as Hedging Instrument [Member]	Dec. 31, 2011 FPL [Member] Not Designated as Hedging Instrument [Member]	Sep. 30, 2012 FPL [Member] Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Current derivative assets [Member]		Dec. 31, 2011 FPL [Member] Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Current derivative assets [Member]		Sep. 30, 2012 FPL [Member] Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Current derivative liabilities [Member]	Dec. 31, 2011 FPL [Member] Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Current derivative liabilities [Member]	Sep. 30, 2012 FPL [Member] Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Non Current Other Assets Member		Dec. 31, 2011 FPL [Member] Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Non Current Other Assets Member		Sep. 30, 2012 FPL [Member] Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Noncurrent derivative liabilities [Member]		Dec. 31, 2011 FPL [Member] Not Designated as Hedging Instrument [Member] Commodity contracts [Member] Noncurrent derivative liabilities [Member]		Sep. 30, 2012 FPL [Member] Not Designated as Hedging Instrument [Member] Foreign currency swaps [Member] Current derivative liabilities [Member]	Dec. 31, 2011 FPL [Member] Not Designated as Hedging Instrument [Member] Foreign currency swaps [Member] Current derivative liabilities [Member]	Sep. 30, 2012 FPL [Member] Not Designated as Hedging Instrument [Member] Foreign currency swaps [Member] Non Current Other Assets Member	Dec. 31, 2011 FPL [Member] Not Designated as Hedging Instrument [Member] Foreign currency swaps [Member] Non Current Other Assets Member
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 4,858	$ 7,024	$ 922	$ 1,127	$ 1,775	$ 3,358	$ 1,913	$ 1,290	$ 233	$ 1,222	$ 0	$ 0	$ 15	$ 27	$ 80	$ 37	$ 26	$ 22	$ 0	$ 0	$ 54	$ 15	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0			$ 87	$ 14	$ 12	[1]	$ 11	[1]	$ 43	$ 1	$ 32	[2]	$ 2	[2]	$ 0	[3]	$ 0	[3]	$ 0	$ 0	$ 0	$ 0
Derivative Liability, Fair Value, Gross Liability	$ 4,009	$ 6,758	$ 426	$ 432	$ 2,233	$ 4,494	$ 884	$ 250	$ 464	$ 1,579	$ 2	$ 3	$ 0	$ 0	$ 399	$ 326	$ 0	$ 0	$ 97	$ 60	$ 0	$ 0	$ 294	$ 260	$ 3	$ 3	$ 5	$ 3			$ 114	$ 515	$ 4	[1]	$ 1	[1]	$ 110	$ 513	$ 0	[2]	$ 0	[2]	$ 0	[3]	$ 1	[3]	$ 0	$ 0	$ 0	$ 0

[1] Included in current other assets on FPL's condensed consolidated balance sheets.

[2] Included in noncurrent other assets on FPL's condensed consolidated balance sheets.

[3] Included in noncurrent other liabilities on FPL's condensed consolidated balance sheets.

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Financial Instruments (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2012		Dec. 31, 2011
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other investments, primarily notes receivable	$ 41		$ 35
Other investments:
Special use funds: equity method investments	229		164
Special use funds: loans	34		39
Available for sale debt securities amortized cost	1,753		1,638
Available for sale equity securities amortized cost	1,437		1,425
Held to maturity notes receivable maturity date - high	2029
Special use funds: storm fund assets	127
Special use funds: nuclear decommissioning fund assets	4,096
Special use funds: nuclear decommissioning funds weighted average maturity (in years)	6 years
Special use funds: storm fund weighted average maturity (in years)	3 years
Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Special use funds	4,223	[1]	3,867	[1]
Other investments:
Notes receivable	500		503
Debt securities	115	[2]	89	[2]
Equity securities	61		80
Long-term debt, including current maturities	24,769		21,614
Interest rate swaps - net unrealized gains (losses)	(311)		(283)
Foreign currency swaps - net unrealized gains (losses)	5		18
Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Special use funds	4,223	[1]	3,867	[1]
Other investments:
Notes receivable	681	[3]	535	[3]
Debt securities	115	[4]	89	[4]
Equity securities	75	[5]	159	[5]
Long-term debt, including current maturities	27,674	[6]	23,699	[6]
Interest rate swaps - net unrealized gains (losses)	(311)	[4]	(283)	[4]
Foreign currency swaps - net unrealized gains (losses)	5	[4]	18	[4]
Significant Other Observable Inputs (Level 2) [Member] | Estimated Fair Value [Member]
Other investments:
Long-term debt, including current maturities	15,873		15,035
FPL [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other investments, primarily notes receivable	8		4
Other investments:
Special use funds: equity method investments	144		112
Special use funds: loans	28		24
Available for sale debt securities amortized cost	1,417		1,321
Available for sale equity securities amortized cost	791		864
Special use funds: nuclear decommissioning fund assets	2,840
Special use funds: nuclear decommissioning funds weighted average maturity (in years)	6 years
FPL [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Special use funds	2,967	[1]	2,737	[1]
Other investments:
Long-term debt, including current maturities	8,084		7,533
FPL [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Special use funds	2,967	[1]	2,737	[1]
Other investments:
Long-term debt, including current maturities	$ 9,984	[6]	$ 9,078	[6]

[1] At September 30, 2012, includes $229 million of investments accounted for under the equity method and $34 million of loans not measured at fair value on a recurring basis ($144 million and $28 million, respectively, for FPL). At December 31, 2011, includes $164 million of investments accounted for under the equity method and $39 million of loans not measured at fair value on a recurring basis ($112 million and $24 million, respectively, for FPL). For the remaining balances, see Note 3 for classification by major security type and hierarchy level. The amortized cost of debt and equity securities is $1,753 million and $1,437 million, respectively, at September 30, 2012 and $1,638 million and $1,425 million, respectively, at December 31, 2011 ($1,417 million and $791 million, respectively, at September 30, 2012 and $1,321 million and $864 million, respectively, at December 31, 2011 for FPL).

[2] Classified as trading securities.

[3] Classified as held to maturity. 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 standings and ratings and market-related information. As of September 30, 2012, NEE had no notes receivable reported in non-accrual status.

[4] See Note 3.

[5] Primarily modeled internally based on recent market information including, among other things, private offerings of the securities (Level 3).

[6] As of September 30, 2012 and December 31, 2011, $15,873 million and $15,035 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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CONDENSED CONSOLIDATED STATEMENTS OF INCOME (unaudited) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
OPERATING REVENUE	$ 3,843	$ 4,382	$ 10,881	$ 11,476
OPERATING EXPENSES
Fuel, purchased power and interchange	1,526	1,911	3,943	4,872
Other operations and maintenance	776	748	2,347	2,212
Impairment charges	0	0	0	51
Depreciation and amortization	467	496	1,121	1,236
Taxes other than income taxes and other	325	316	855	859
Total operating expenses	3,094	3,471	8,266	9,230
OPERATING INCOME	749	911	2,615	2,246
OTHER INCOME (DEDUCTIONS)
Interest expense	(259)	(265)	(795)	(775)
Loss on natural gas-fired generating assets held for sale	0	(148)	0	(148)
Equity in earnings (losses) of equity method investees	16	28	17	57
Allowance for equity funds used during construction	21	7	52	28
Interest income	20	21	62	58
Gains on disposal of assets - net	53	37	120	79
Other than temporary impairment losses on securities held in nuclear decommissioning funds	(4)	(30)	(11)	(34)
Other - net	(27)	4	(25)	18
Total other deductions - net	(180)	(346)	(580)	(717)
INCOME BEFORE INCOME TAXES	569	565	2,035	1,529
INCOME TAXES	154	158	553	273
NET INCOME	415	407	1,482	1,256
Earnings per share of common stock:
Basic (in dollars per share)	$ 0.99	$ 0.98	$ 3.57	$ 3.01
Assuming dilution (in dollars per share)	$ 0.98	$ 0.97	$ 3.55	$ 3.00
Dividends per share of common stock (in dollars per share)	$ 0.60	$ 0.55	$ 1.80	$ 1.65
Weighted-average number of common shares outstanding:
Basic (in shares)	419.3	417.4	415.6	416.7
Assuming dilution (in shares)	421.7	419.8	418.0	419.1
FPL [Member]
OPERATING REVENUE	2,975	3,152	7,778	8,200
OPERATING EXPENSES
Fuel, purchased power and interchange	1,280	1,479	3,301	3,854
Other operations and maintenance	427	429	1,305	1,237
Depreciation and amortization	254	299	496	653
Taxes other than income taxes and other	295	289	814	822
Total operating expenses	2,256	2,496	5,916	6,566
OPERATING INCOME	719	656	1,862	1,634
OTHER INCOME (DEDUCTIONS)
Interest expense	(104)	(101)	(314)	(287)
Allowance for equity funds used during construction	14	6	36	26
Other - net	0	1	0	(2)
Total other deductions - net	(90)	(94)	(278)	(263)
INCOME BEFORE INCOME TAXES	629	562	1,584	1,371
INCOME TAXES	237	215	600	519
NET INCOME	$ 392	$ 347	$ 984	$ 852

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Debt (Details) (USD $)	9 Months Ended																9 Months Ended							0 Months Ended
	Sep. 30, 2012 NextEra Energy Capital Holdings and NextEra Energy Resources subsidiary [Member] Canadian revolving credit facilities [Member]		Sep. 30, 2012 NextEra Energy Capital Holdings and NextEra Energy Resources subsidiary [Member] Eurodollar denominated revolving loan [Member]		Sep. 30, 2012 NextEra Energy Resources Subsidiaries [Member] Eurodollar denominated senior secured limited recourse loan due 2030 [Member]		Sep. 30, 2012 NextEra Energy Resources Subsidiaries [Member] Eurodollar denominated senior secured limited recourse loan due 2015 [Member]		Sep. 30, 2012 Lone Star [Member] Senior secured limited-recourse loan [Member]		Sep. 30, 2012 FPL [Member] First mortgage bonds issued May 2012 [Member]	Sep. 30, 2012 Capital Holdings [Member] Junior subordinated debentures sold in March 2012 [Member]	Sep. 30, 2012 Capital Holdings [Member] Debentures related to NEE equity units [Member]	Sep. 30, 2012 Capital Holdings [Member] Junior subordinated debentures sold in June 2012 [Member]	Sep. 30, 2012 Capital Holdings [Member] Debentures Related to NEE Equity Units Sold September 2012 [Member]	Sep. 30, 2012 Capital Holdings [Member] Debentures Sold September 2012 [Member]	Sep. 30, 2012 NextEra Energy Resources subsidiary [Member] Senior secured limited-recourse loan [Member]		Sep. 30, 2012 NextEra Energy Resources subsidiary [Member] Limited recourse term loan [Member]		Sep. 30, 2012 NextEra Energy Resources subsidiary [Member] Canadian Senior Secrued Limited Recourse Notes [Member]	Sep. 30, 2012 NEE Equity Units 2012 [Member]	May 31, 2012 NEE Equity Units 2012 [Member]	Jun. 01, 2012 NEE Equity Units 2009 [Member]	May 31, 2012 NEE Equity Units 2009 [Member]
Debt Instrument [Line Items]
Amount Of Equity Units Sold																						$ 650,000,000	$ 600,000,000
Interest Rate Terms	Variable	[1]	Variable	[1]	Variable	[1],[2]	Variable	[1]	Variable	[1]							Variable	[1],[2]	Variable	[1],[2]
Line of credit facilities and loans, increase, additional borrowings	146,000,000		81,000,000		247,000,000		48,000,000		150,000,000
Interest Rate (as a percent)											4.05%	5.70%	1.70%	5.625%	1.60%	1.20%					4.881%
Principal Amount											600,000,000	400,000,000	600,000,000	350,000,000	650,000,000	500,000,000	232,000,000		99,000,000		176,000,000
Stated Amount Of Each Equity Unit																						$ 50	$ 50
Undivided Beneficial Ownership Interest Per Debenture																						5.00%	5.00%
Principal Amount Of Each Debenture																						1,000	1,000
Price Per Share Of Stock Purchase Contract Low Range																						$ 67.15	$ 64.35
Number Of Shares Subject To Antidilution Adjustments If Purchased On Final Settlement Date At Equal To Or Greater Than High Range Threshold																						0.6205	0.6475
Price Per Share Of Stock Purchase Contract High Range																						$ 80.58	$ 77.22
Number Of Shares Subject To Antidilution Adjustments If Purchased On Final Settlement Date At Less Than Or Equal To Low Range Threshold																						0.7446	0.7770
Trading Period Over Which Market Value Is Determined By Reference To Average Closing Prices Of Common Stock																						20 days	20 days
Rate Of Total Annual Distributions On Equity Units																						5.889%	5.599%
Rate Of Total Annual Distributions On Debentures																						1.60%	1.70%		1.611%
Rate Of Payments On Stock Purchase Contracts																						4.289%	3.899%
Debentures remarketed in May 2012																									350,000,000
Stock Issued During Period, Shares, New Issues																								5,400,500
Stock Issued During Period, Value, New Issues																								$ 350,000,000

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

[2] Interest rate swap agreements were entered into with respect to these issuances.

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CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) (Parenthetical) (USD $) In Millions, except Share data, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
PROPERTY, PLANT AND EQUIPMENT
Total property, plant and equipment - net	$ 47,693	$ 42,490
CURRENT ASSETS
Customer receivables, allowances	14	11
OTHER ASSETS
Securitized storm-recovery costs	462	517
CAPITALIZATION
Long-term debt	22,714	20,810
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	423,000,000	416,000,000
Related to VIEs [Member]
PROPERTY, PLANT AND EQUIPMENT
Total property, plant and equipment - net	3,900	3,063
OTHER ASSETS
Securitized storm-recovery costs	284	317
CAPITALIZATION
Long-term debt	1,301	1,364
FLORIDA POWER & LIGHT COMPANY
CURRENT ASSETS
Customer receivables, allowances	10	8
OTHER ASSETS
Securitized storm-recovery costs	462	517
CAPITALIZATION
Long-term debt	7,632	7,483
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
FLORIDA POWER & LIGHT COMPANY | Related to VIEs [Member]
OTHER ASSETS
Securitized storm-recovery costs	284	317
CAPITALIZATION
Long-term debt	$ 386	$ 437

XML

Derivative Instruments (Credit-Risk-Related Contingent Features) (Details) (USD $)	Sep. 30, 2012
Derivative [Line Items]
Fair value of derivative instruments with credit-risk-related contingent features that were in a liability position	$ 2,200,000,000
Total required posted collateral should FPL's and Capital Holdings' credit ratings fall to BBB/Baa2	350,000,000
Total required posted collateral should FLP's and Capital Holdings' credit ratings fall below investment grade	2,200,000,000
Additional collateral requirements if non-ratings based contract provisions are triggered	600,000,000
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	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	115,000,000
Total required posted collateral should FPL's and Capital Holdings' credit ratings fall to BBB/Baa2	10,000,000
Total required posted collateral should FLP's and Capital Holdings' credit ratings fall below investment grade	500,000,000
Additional collateral requirements if non-ratings based contract provisions are triggered	$ 100,000,000

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Derivative Instruments (Tables)

9 Months Ended

Sep. 30, 2012

Derivative [Line Items]

Net fair values of mark-to-market derivative instrument assets (liabilities)

The net fair values of NEE's and FPL's mark-to-market derivative instrument assets (liabilities) are included on the condensed consolidated balance sheets as follows:

	NEE						FPL
	September 30, 2012			December 31, 2011			September 30, 2012				December 31, 2011
	(millions)
Current derivative assets(a)	$	482		$	611		$	8		(b)	$	10		(b)
Noncurrent derivative assets(c)	944			973			32			(d)	2			(d)
Current derivative liabilities(e)	(486		)	(1,090		)	(67		)		(512		)
Noncurrent derivative liabilities(f)	(530		)	(541		)	—				(1		)	(g)
Total mark-to-market derivative instrument assets (liabilities)	$	410		$	(47	)	$	(27	)		$	(501	)

————————————

(a) At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $40 million and $106 million (none at FPL), respectively, in margin cash collateral received from counterparties.

(b) Included in current other assets on FPL's condensed consolidated balance sheets.

(c) At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $154 million and $109 million (none at FPL), respectively, in margin cash collateral received from counterparties.

(d) Included in noncurrent other assets on FPL's condensed consolidated balance sheets.

(e) At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $74 million and $112 million (none at FPL), respectively, in margin cash collateral provided to counterparties.

(f) At December 31, 2011, NEE's balance reflects the netting of approximately $79 million (none at FPL) in margin cash collateral provided to counterparties.

(g) Included in noncurrent other liabilities on FPL's condensed consolidated balance sheets.

Net notional volumes

At September 30, 2012, NEE and FPL had derivative commodity contracts for the following net notional volumes:

Commodity Type	NEE			FPL
	(millions)
Power	(46	)	mwh(a)	—
Natural gas	1,221		mmbtu(b)	837	mmbtu(b)
Oil	(7	)	barrels	—

————————————

(a) Megawatt-hours

(b) One million British thermal units

Cash Flow Hedging [Member]

Derivative [Line Items]

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

The fair values of NEE's derivatives designated as hedging instruments for accounting purposes (none at FPL) are presented below as gross asset and liability values, as required by disclosure rules.

	September 30, 2012				December 31, 2011
	Derivative Assets		Derivative Liabilities		Derivative Assets		Derivative Liabilities
	(millions)
Interest rate swaps:
Current derivative assets	$	26	$	—	$	22	$	—
Current derivative liabilities	—		97		—		60
Noncurrent derivative assets	54		—		15		—
Noncurrent derivative liabilities	—		294		—		260
Foreign currency swap:
Current derivative liabilities	—		3		—		3
Noncurrent derivative liabilities	—		5		—		3
Total	$	80	$	399	$	37	$	326

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 September 30,
	2012												2011
	Commodity Contracts		Interest Rate Swaps			Foreign Currency Swap				Total			Commodity Contracts		Interest Rate Swaps			Foreign Currency Swaps				Total
	(millions)
Gains (losses) recognized in OCI	$	—	$	(39	)	$	(6	)		$	(45	)	$	—	$	(236	)	$	(14	)		$	(250	)
Gains (losses) reclassified from AOCI to net income(a)	$	2	$	(14	)	$	2		(b)	$	(10	)	$	11	$	(21	)	$	5		(b)	$	(5	)

————————————

(a) Included in operating revenues for commodity contracts and interest expense for interest rate swaps. In 2011, excludes approximately $21 million of net losses related to discontinuance of certain cash flow hedges. See further discussion above.

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

	Nine Months Ended September 30,
	2012												2011
	Commodity Contracts		Interest Rate Swaps			Foreign Currency Swap				Total			Commodity Contracts		Interest Rate Swaps			Foreign Currency Swaps				Total
	(millions)
Gains (losses) recognized in OCI	$	—	$	(104	)	$	(16	)		$	(120	)	$	—	$	(353	)	$	(20	)		$	(373	)
Gains (losses) reclassified from AOCI to net income(a)	$	6	$	(44	)	$	(4	)	(b)	$	(42	)	$	30	$	(64	)	$	1		(c)	$	(33	)

————————————

(a) Included in operating revenues for commodity contracts and interest expense for interest rate swaps. In 2011, excludes approximately $21 million of net losses related to discontinuance of certain cash flow hedges. See further discussion above.

(b) Loss of approximately $2 million is included in interest expense and the balance is included in other - net.

(c) Loss of approximately $4 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 in Statement of Financial Position, Fair Value [Table Text Block]

The fair values of NEE's and FPL's derivatives not designated as hedging instruments for accounting purposes are presented below as gross asset and liability values, as required by disclosure rules.  However, the majority of the underlying contracts are subject to master netting arrangements and would not be contractually settled on a gross basis.

	September 30, 2012										December 31, 2011
	NEE				FPL						NEE				FPL
	Derivative Assets		Derivative Liabilities		Derivative Assets			Derivative Liabilities			Derivative Assets		Derivative Liabilities		Derivative Assets			Derivative Liabilities
	(millions)
Commodity contracts:
Current derivative assets	$	922	$	426	$	12	(a)	$	4	(a)	$	1,127	$	432	$	11	(a)	$	1	(a)
Current derivative liabilities	1,775		2,233		43			110			3,358		4,494		1			513
Noncurrent derivative assets	1,913		884		32		(b)	—			1,290		250		2		(b)	—
Noncurrent derivative liabilities	233		464		—			—			1,222		1,579		—			1		(c)
Foreign currency swap:
Current derivative liabilities	—		2		—			—			—		3		—			—
Noncurrent derivative assets	15		—		—			—			27		—		—			—
Total	$	4,858	$	4,009	$	87		$	114		$	7,024	$	6,758	$	14		$	515

————————————

(a) Included in current other assets on FPL's condensed consolidated balance sheets.

(b) Included in noncurrent other assets on FPL's condensed consolidated balance sheets.

(c) Included in noncurrent other liabilities on FPL's condensed consolidated balance sheets.

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 (none at FPL) as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(millions)
Commodity contracts(a):
Operating revenues	$	(218	)	$	(50	)	$	102		$	(48	)
Fuel, purchased power and interchange	(4		)	10			36			8
Foreign currency swap - other - net	9			23			(13		)	20
Interest rate contracts - other - net	—			(16		)	—			(11		)
Total	$	(213	)	$	(33	)	$	125		$	(31	)

————————————

(a) For the three months ended September 30, 2012 and 2011, FPL recorded approximately $90 million of gains and $232 million of losses, respectively, related to commodity contracts as regulatory liabilities and regulatory assets, respectively, on its condensed consolidated balance sheets.  For the nine months ended September 30, 2012 and 2011, FPL recorded approximately $86 million and $300 million of losses, respectively, related to commodity contracts as regulatory assets on its condensed consolidated balance sheets.

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Fair Value Measurements (Details) (Fair value measurements made on a recurring basis [Member], USD $) In Millions, unless otherwise specified	Sep. 30, 2012		Dec. 31, 2011
Cash equivalents:
Equity securities	$ 22		$ 159
Special use funds:
Equity securities	2,106		1,915
U.S. Government and municipal bonds	664		675
Corporate debt securities	549		516
Mortgage-backed securities	594		511
Other debt securities	47		47
Other investments:
Equity securities	12		4
U.S. Government and municipal bonds	11		8
Corporate debt securities	52		43
Mortgage-backed securities	47		33
Other	10		10
Derivatives:
Commodity contracts	1,331	[1]	1,520	[1]
Interest rate swaps	80	[1]	37	[1]
Foreign currency swaps	15	[1]	27	[1]
Derivatives:
Commodity contracts	615	[1]	1,302	[1]
Interest rate swaps	391	[1]	320	[1]
Foreign currency swaps	10	[1]	9	[1]
Fair value of investments in commingled funds whose underlying investments would be Level 1 if those investments were held directly by the registrant	1,217		1,086
FPL [Member]
Cash equivalents:
Equity securities	1		11
Special use funds:
Equity securities	1,292		1,184
U.S. Government and municipal bonds	574		592
Corporate debt securities	381		359
Mortgage-backed securities	513		434
Other debt securities	35		32
Derivatives:
Commodity contracts	40	[1]	12	[1]
Derivatives:
Commodity contracts	67	[1]	513	[1]
Fair value of investments in commingled funds whose underlying investments would be Level 1 if those investments were held directly by the registrant	1,093		979
Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member]
Cash equivalents:
Equity securities	22		159
Special use funds:
Equity securities	813		709
U.S. Government and municipal bonds	495		508
Corporate debt securities	0		0
Mortgage-backed securities	0		0
Other debt securities	0		0
Other investments:
Equity securities	12		4
U.S. Government and municipal bonds	11		8
Corporate debt securities	0		0
Mortgage-backed securities	0		0
Other	5		5
Derivatives:
Commodity contracts	1,407		2,448
Interest rate swaps	0		0
Foreign currency swaps	0		0
Derivatives:
Commodity contracts	1,461		2,588
Interest rate swaps	0		0
Foreign currency swaps	0		0
Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | FPL [Member]
Cash equivalents:
Equity securities	1		11
Special use funds:
Equity securities	150		128
U.S. Government and municipal bonds	442		458
Corporate debt securities	0		0
Mortgage-backed securities	0		0
Other debt securities	0		0
Derivatives:
Commodity contracts	0		0
Derivatives:
Commodity contracts	0		0
Significant Other Observable Inputs (Level 2) [Member]
Cash equivalents:
Equity securities	0		0
Special use funds:
Equity securities	1,293	[2]	1,206	[3]
U.S. Government and municipal bonds	169		167
Corporate debt securities	549		516
Mortgage-backed securities	594		511
Other debt securities	47		47
Other investments:
Equity securities	0		0
U.S. Government and municipal bonds	0		0
Corporate debt securities	52		43
Mortgage-backed securities	47		33
Other	5		5
Derivatives:
Commodity contracts	2,605		3,478
Interest rate swaps	80		37
Foreign currency swaps	15		27
Derivatives:
Commodity contracts	2,197		3,582
Interest rate swaps	391		320
Foreign currency swaps	10		9
Significant Other Observable Inputs (Level 2) [Member] | FPL [Member]
Cash equivalents:
Equity securities	0		0
Special use funds:
Equity securities	1,142	[2]	1,056	[2]
U.S. Government and municipal bonds	132		134
Corporate debt securities	381		359
Mortgage-backed securities	513		434
Other debt securities	35		32
Derivatives:
Commodity contracts	82		8
Derivatives:
Commodity contracts	114		513
Significant Unobservable Inputs (Level 3) [Member]
Cash equivalents:
Equity securities	0		0
Special use funds:
Equity securities	0		0
U.S. Government and municipal bonds	0		0
Corporate debt securities	0		0
Mortgage-backed securities	0		0
Other debt securities	0		0
Other investments:
Equity securities	0		0
U.S. Government and municipal bonds	0		0
Corporate debt securities	0		0
Mortgage-backed securities	0		0
Other	0		0
Derivatives:
Commodity contracts	831		1,071
Interest rate swaps	0		0
Foreign currency swaps	0		0
Derivatives:
Commodity contracts	349		585
Interest rate swaps	0		0
Foreign currency swaps	0		0
Significant Unobservable Inputs (Level 3) [Member] | FPL [Member]
Cash equivalents:
Equity securities	0		0
Special use funds:
Equity securities	0		0
U.S. Government and municipal bonds	0		0
Corporate debt securities	0		0
Mortgage-backed securities	0		0
Other debt securities	0		0
Derivatives:
Commodity contracts	5		6
Derivatives:
Commodity contracts	0		2
Netting [Member]
Cash equivalents:
Equity securities	0	[4]	0	[4]
Special use funds:
Equity securities	0	[4]	0	[4]
U.S. Government and municipal bonds	0	[4]	0	[4]
Corporate debt securities	0	[4]	0	[4]
Mortgage-backed securities	0	[4]	0	[4]
Other debt securities	0	[4]	0	[4]
Other investments:
Equity securities	0	[4]	0	[4]
U.S. Government and municipal bonds	0	[4]	0	[4]
Corporate debt securities	0	[4]	0	[4]
Mortgage-backed securities	0	[4]	0	[4]
Other	0	[4]	0	[4]
Derivatives:
Commodity contracts	(3,512)	[4]	(5,477)	[4]
Interest rate swaps	0	[4]	0	[4]
Foreign currency swaps	0	[4]	0	[4]
Derivatives:
Commodity contracts	(3,392)	[4]	(5,453)	[4]
Interest rate swaps	0	[4]	0	[4]
Foreign currency swaps	0	[4]	0	[4]
Netting [Member] | FPL [Member]
Cash equivalents:
Equity securities	0	[4]	0	[4]
Special use funds:
Equity securities	0	[4]	0	[4]
U.S. Government and municipal bonds	0	[4]	0	[4]
Corporate debt securities	0	[4]	0	[4]
Mortgage-backed securities	0	[4]	0	[4]
Other debt securities	0	[4]	0	[4]
Derivatives:
Commodity contracts	(47)	[4]	(2)	[4]
Derivatives:
Commodity contracts	$ (47)	[4]	$ (2)	[4]

[1] See Note 2 for a reconciliation of net derivatives to NEE's and FPL's condensed consolidated balance sheets.

[2] At NEE, approximately $1,217 million ($1,093 million at FPL) are invested in commingled funds whose underlying investments would be Level 1 if those investments were held directly by NEE or FPL.

[3] At NEE, approximately $1,086 million ($979 million at FPL) are invested in commingled funds whose underlying investments would be Level 1 if those investments were held directly by NEE or FPL.

[4] Includes the effect of the contractual ability to settle contracts under master netting arrangements and margin cash collateral payments and receipts.

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Financial Instruments (Tables)

9 Months Ended

Sep. 30, 2012

Financial Instruments [Abstract]

Estimates of the fair value of financial instruments

The following estimates of the fair value of financial instruments have been made primarily using available market information.  However, the use of different market assumptions or methods of valuation could result in different estimated fair values.

	September 30, 2012								December 31, 2011
	Carrying Amount				Estimated Fair Value				Carrying Amount				Estimated Fair Value
	(millions)
NEE:
Special use funds	$	4,223		(a)	$	4,223		(a)	$	3,867		(a)	$	3,867		(a)
Other investments:
Notes receivable	$	500			$	681		(b)	$	503			$	535		(b)
Debt securities	$	115		(c)	$	115		(d)	$	89		(c)	$	89		(d)
Equity securities	$	61			$	75		(e)	$	80			$	159		(e)
Long-term debt, including current maturities	$	24,769			$	27,674		(f)	$	21,614			$	23,699		(f)
Interest rate swaps - net unrealized losses	$	(311	)		$	(311	)	(d)	$	(283	)		$	(283	)	(d)
Foreign currency swaps - net unrealized gains	$	5			$	5		(d)	$	18			$	18		(d)
FPL:
Special use funds	$	2,967		(a)	$	2,967		(a)	$	2,737		(a)	$	2,737		(a)
Long-term debt, including current maturities	$	8,084			$	9,984		(f)	$	7,533			$	9,078		(f)

————————————

(a) At September 30, 2012, includes $229 million of investments accounted for under the equity method and $34 million of loans not measured at fair value on a recurring basis ($144 million and $28 million, respectively, for FPL).  At December 31, 2011, includes $164 million of investments accounted for under the equity method and $39 million of loans not measured at fair value on a recurring basis ($112 million and $24 million, respectively, for FPL).  For the remaining balances, see Note 3 for classification by major security type and hierarchy level.  The amortized cost of debt and equity securities is $1,753 million and $1,437 million, respectively, at September 30, 2012 and $1,638 million and $1,425 million, respectively, at December 31, 2011 ($1,417 million and $791 million, respectively, at September 30, 2012 and $1,321 million and $864 million, respectively, at December 31, 2011 for FPL).

(b) Classified as held to maturity.  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 standings and ratings and market-related information.  As of September 30, 2012, NEE had no notes receivable reported in non-accrual status.

(c) Classified as trading securities.

(d) See Note 3.

(e) Primarily modeled internally based on recent market information including, among other things, private offerings of the securities (Level 3).

(f) As of September 30, 2012 and December 31, 2011, $15,873 million and $15,035 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				NEE				FPL
	Three Months Ended September 30,				Three Months Ended September 30,				Nine Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011		2012		2011		2012		2011
	(millions)
Realized gains	$	75	$	69	$	20	$	22	$	206	$	156	$	81	$	60
Realized losses	$	16	$	27	$	12	$	17	$	48	$	70	$	34	$	51
Proceeds from sale or maturity of securities	$	953	$	992	$	592	$	675	$	3,890	$	3,567	$	2,949	$	2,483

Unrealized losses on available for sale debt securities at September 30, 2012 and December 31, 2011 were not material to NEE or FPL.  The unrealized gains on available for sale securities are as follows:

	NEE				FPL
	September 30, 2012		December 31, 2011		September 30, 2012		December 31, 2011
	(millions)
Equity securities	$	694	$	546	$	526	$	376
U.S. Government and municipal bonds	$	32	$	46	$	29	$	43
Corporate debt securities	$	43	$	31	$	32	$	24
Mortgage-backed securities	$	25	$	27	$	22	$	24
Other debt securities	$	2	$	3	$	2	$	3

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	$ 1,482	$ 1,256
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	1,121	1,236
Nuclear fuel amortization	194	210
Loss on natural gas-fired generating assets held for sale	0	148
Impairment charges	0	51
Unrealized (gains) losses on marked to market energy contracts	(89)	182
Deferred income taxes	517	274
Cost recovery clauses and franchise fees	115	71
Changes in prepaid option premiums and derivative settlements	(36)	23
Equity in earnings (losses) of equity method investees	(17)	(57)
Distributions of earnings from equity method investees	20	67
Allowance for equity funds used during construction	(52)	(28)
Gains on disposal of assets - net	(120)	(79)
Other than temporary impairment losses on securities held in nuclear decommissioning funds	11	34
Other - net	236	121
Changes in operating assets and liabilities:
Customer receivables	(255)	(228)
Other receivables	(92)	56
Materials, supplies and fossil fuel inventory	21	(269)
Other current assets	(51)	(27)
Other assets	(50)	(83)
Accounts payable	1	30
Customer deposits	(34)	5
Margin cash collateral	110	(28)
Income taxes	(6)	106
Interest and other taxes	270	259
Other current liabilities	(27)	(83)
Other liabilities	(112)	(130)
Net cash provided by operating activities	3,157	3,117
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL	(3,061)	(2,128)
Independent power and other investments of NextEra Energy Resources	(3,025)	(1,654)
Cash grants under the American Recovery and Reinvestment Act of 2009	105	503
Nuclear fuel purchases	(202)	(331)
Other capital expenditures	(401)	(204)
Change in loan proceeds restricted for construction	212	(596)
Proceeds from sale or maturity of securities in special use funds	3,890	3,567
Purchases of securities in special use funds	(3,994)	(3,638)
Proceeds from sale or maturity of other securities	219	399
Purchases of other securities	(259)	(431)
Other - net	15	91
Net cash used in investing activities	(6,501)	(4,422)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	4,226	2,917
Retirements of long-term debt	(1,321)	(1,688)
Proceeds from sale of differential membership interests	414	210
Payments to differential membership investors	(53)	0
Net change in short-term debt	396	946
Issuances of common stock - net	386	39
Repurchase of common stock	(19)	0
Dividends	(752)	(689)
Other - net	(64)	(92)
Net cash provided by (used in) financing activities	3,213	1,643
Net increase (decrease) in cash and cash equivalents	(131)	338
Cash and cash equivalents at beginning of period	377	302
Cash and cash equivalents at end of period	246	640
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	943	851
FPL [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	984	852
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	496	653
Nuclear fuel amortization	74	111
Deferred income taxes	656	439
Cost recovery clauses and franchise fees	115	71
Allowance for equity funds used during construction	(36)	(26)
Other - net	51	21
Changes in operating assets and liabilities:
Customer receivables	(305)	(286)
Other receivables	16	14
Materials, supplies and fossil fuel inventory	24	(219)
Other current assets	(35)	(33)
Other assets	(41)	(48)
Accounts payable	60	69
Customer deposits	(32)	4
Income taxes	74	(67)
Interest and other taxes	264	228
Other current liabilities	(55)	1
Other liabilities	(8)	(36)
Net cash provided by operating activities	2,302	1,748
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL	(3,061)	(2,128)
Cash grants under the American Recovery and Reinvestment Act of 2009	0	202
Nuclear fuel purchases	(137)	(223)
Proceeds from sale or maturity of securities in special use funds	2,949	2,483
Purchases of securities in special use funds	(3,031)	(2,534)
Other - net	27	32
Net cash used in investing activities	(3,253)	(2,168)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	594	248
Retirements of long-term debt	(50)	(45)
Net change in short-term debt	142	307
Capital contribution from NextEra Energy	240	310
Dividends	0	(400)
Other - net	9	10
Net cash provided by (used in) financing activities	935	430
Net increase (decrease) in cash and cash equivalents	(16)	10
Cash and cash equivalents at beginning of period	36	20
Cash and cash equivalents at end of period	20	30
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	$ 445	$ 420

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net income of NextEra Energy	$ 415	$ 407	$ 1,482	$ 1,256
Net unrealized gains (losses) on cash flow hedges:
Effective portion of net unrealized gains (losses), net of tax	(30)	(158)	(79)	(248)
Reclassification from AOCI to net income, net of tax	3	16	24	36
Net unrealized gains (losses) on available for sale securities:
Net unrealized gains (losses) on securities still held, net of tax	26	(43)	64	(20)
Reclassification from AOCI to net income, net of tax	(27)	(25)	(64)	(47)
Defined benefit pension and other benefits plans, net of tax	0	0	(6)	6
Net unrealized gains (losses) on foreign currency translation, net of tax	3	(19)	6	(7)
Other comprehensive income (loss) related to equity method investee, net of tax	(4)	0	(10)	0
Other Comprehensive Income (Loss), Net of Tax	(29)	(229)	(65)	(280)
Comprehensive income (loss) of NextEra Energy	$ 386	$ 178	$ 1,417	$ 976

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Segment Information

9 Months Ended

Sep. 30, 2012

Segment Reporting [Abstract]

Segment Information

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 September 30,
	2012										2011
	FPL		NEER(a)			Corporate and Other			NEE Consoli- dated		FPL		NEER(a)			Corporate and Other				NEE Consoli- dated
									(millions)
Operating revenues	$	2,975	$	808		$	60		$	3,843	$	3,152	$	1,172		$	58			$	4,382
Operating expenses	$	2,256	$	785		$	53		$	3,094	$	2,496	$	920		$	55			$	3,471
Net income	$	392	$	44	(b)	$	(21	)	$	415	$	347	$	67	(b)	$	(7	)	(c)	$	407

	Nine Months Ended September 30,
	2012										2011
	FPL		NEER(a)			Corporate and Other			NEE Consoli- dated		FPL		NEER(a)			Corporate and Other			NEE Consoli- dated
									(millions)
Operating revenues	$	7,778	$	2,929		$	174		$	10,881	$	8,200	$	3,110		$	166		$	11,476
Operating expenses	$	5,916	$	2,201		$	149		$	8,266	$	6,566	$	2,520	(d)	$	144		$	9,230
Net income	$	984	$	516	(b)	$	(18	)	$	1,482	$	852	$	371	(b)(e)	$	33	(c)(f)	$	1,256

	September 30, 2012								December 31, 2011
	FPL		NEER		Corporate and Other		NEE Consoli- dated		FPL		NEER		Corporate and Other		NEE Consoli- dated
							(millions)
Total assets	$	34,120	$	25,761	$	2,168	$	62,049	$	31,816	$	23,459	$	1,913	$	57,188

————————————

(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) See Note 5 for a discussion of NEER's tax benefits related to PTCs. 2011 includes after-tax loss on natural gas-fired generating assets held for sale of $91 million.  See Note 3 - Nonrecurring Fair Value Measurements.  

(c) Includes after-tax loss on natural gas-fired generating assets held for sale of $6 million.  See Note 3 - Nonrecurring Fair Value Measurements.

(d) Includes impairment charges of approximately $51 million.  See Note 3 - Nonrecurring Fair Value Measurements.

(e) Includes after-tax impairment charges of approximately $31 million.  See Note 3 - Nonrecurring Fair Value Measurements.

(f) Includes the state deferred income tax benefit of approximately $64 million.  See Note 5.

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Document Entity Information Document	9 Months Ended
	Sep. 30, 2012
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	423,206,077
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q3
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2012
FLORIDA POWER & LIGHT COMPANY
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

9 Months Ended

Sep. 30, 2012

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 September 30,
	2012												2011
	NEE (Guarantor)			NEECH			Other(a)			NEE Consoli- dated			NEE (Guarantor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
Operating revenues	$	—		$	871		$	2,972		$	3,843		$	—		$	1,232		$	3,150		$	4,382
Operating expenses	(5		)	(836		)	(2,253		)	(3,094		)	(4		)	(973		)	(2,494		)	(3,471		)
Interest expense	(2		)	(155		)	(102		)	(259		)	(3		)	(164		)	(98		)	(265		)
Equity in earnings of subsidiaries	416			—			(416		)	—			416			—			(416		)	—
Other income (deductions) - net	4			61			14			79			1			(86		)	4			(81		)
Income (loss) before income taxes	413			(59		)	215			569			410			9			146			565
Income tax expense (benefit)	(2		)	(82		)	238			154			3			(60		)	215			158
Net income (loss)	$	415		$	23		$	(23	)	$	415		$	407		$	69		$	(69	)	$	407

	Nine Months Ended September 30,
	2012												2011
	NEE(Guarantor)			NEECH			Other(a)			NEE Consoli- dated			NEE(Guarantor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
Operating revenues	$	—		$	3,112		$	7,769		$	10,881		$	—		$	3,285		$	8,191		$	11,476
Operating expenses	(13		)	(2,346		)	(5,907		)	(8,266		)	(11		)	(2,662		)	(6,557		)	(9,230		)
Interest expense	(8		)	(479		)	(308		)	(795		)	(10		)	(486		)	(279		)	(775		)
Equity in earnings of subsidiaries	1,480			—			(1,480		)	—			1,214			—			(1,214		)	—
Other income (deductions) - net	5			180			30			215			1			40			17			58
Income (loss) before income taxes	1,464			467			104			2,035			1,194			177			158			1,529
Income tax expense (benefit)	(18		)	(29		)	600			553			(62		)	(185		)	520			273
Net income (loss)	$	1,482		$	496		$	(496	)	$	1,482		$	1,256		$	362		$	(362	)	$	1,256

————————————

(a)  Represents FPL and consolidating adjustments.

Condensed Consolidating Statements of Comprehensive Income

	Three Months Ended September 30,
	2012									2011
	NEE (Guarantor)		NEECH			Other(a)		NEE Consoli- dated		NEE (Guarantor)		NEECH			Other(a)		NEE Consoli- dated
								(millions)
Comprehensive income (loss)	$	386	$	(6	)	$	6	$	386	$	178	$	(160	)	$	160	$	178

	Nine Months Ended September 30,
	2012									2011
	NEE (Guarantor)		NEECH		Other(a)			NEE Consoli- dated		NEE (Guarantor)		NEECH		Other(a)			NEE Consoli- dated
								(millions)
Comprehensive income (loss)	$	1,417	$	437	$	(437	)	$	1,417	$	976	$	76	$	(76	)	$	976

————————————

(a) Represents FPL and consolidating adjustments.

Condensed Consolidating Balance Sheets

	September 30, 2012												December 31, 2011
	NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated			NEE (Guaran- tor)			NEECH			Other(a)			NEE Consoli- dated
										(millions)
PROPERTY, PLANT AND EQUIPMENT
Electric utility plant in service and other property	$	31		$	25,778		$	37,621		$	63,430		$	31		$	22,351		$	35,170		$	57,552
Less accumulated depreciation and amortization	(6		)	(4,817		)	(10,914		)	(15,737		)	(3		)	(4,143		)	(10,916		)	(15,062		)
Total property, plant and equipment - net	25			20,961			26,707			47,693			28			18,208			24,254			42,490
CURRENT ASSETS
Cash and cash equivalents	1			226			19			246			1			339			37			377
Receivables	112			1,090			920			2,122			84			1,026			692			1,802
Other	5			1,003			1,061			2,069			5			1,075			1,613			2,693
Total current assets	118			2,319			2,000			4,437			90			2,440			2,342			4,872
OTHER ASSETS
Investment in subsidiaries	15,858			—			(15,858		)	—			14,879			—			(14,879		)	—
Other	745			4,783			4,391			9,919			513			4,849			4,464			9,826
Total other assets	16,603			4,783			(11,467		)	9,919			15,392			4,849			(10,415		)	9,826
TOTAL ASSETS	$	16,746		$	28,063		$	17,240		$	62,049		$	15,510		$	25,497		$	16,181		$	57,188
CAPITALIZATION
Common shareholders' equity	$	15,886		$	3,784		$	(3,784	)	$	15,886		$	14,943		$	4,030		$	(4,030	)	$	14,943
Long-term debt	—			15,082			7,632			22,714			—			13,327			7,483			20,810
Total capitalization	15,886			18,866			3,848			38,600			14,943			17,357			3,453			35,753
CURRENT LIABILITIES
Debt due within one year	—			2,712			924			3,636			—			1,778			379			2,157
Accounts payable	—			522			672			1,194			—			512			679			1,191
Other	289			1,410			1,346			3,045			250			1,520			1,601			3,371
Total current liabilities	289			4,644			2,942			7,875			250			3,810			2,659			6,719
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	—			495			1,190			1,685			—			466			1,145			1,611
Accumulated deferred income taxes	67			1,273			4,826			6,166			68			1,376			4,237			5,681
Other	504			2,785			4,434			7,723			249			2,488			4,687			7,424
Total other liabilities and deferred credits	571			4,553			10,450			15,574			317			4,330			10,069			14,716
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	16,746		$	28,063		$	17,240		$	62,049		$	15,510		$	25,497		$	16,181		$	57,188

————————————

(a) Represents FPL and consolidating adjustments.

Condensed Consolidating Statements of Cash Flows

	Nine Months Ended September 30,
	2012												2011
	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	$	662		$	878		$	1,617		$	3,157		$	979		$	1,071		$	1,067		$	3,117
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases	—			(3,492		)	(3,197		)	(6,689		)	(16		)	(1,950		)	(2,351		)	(4,317		)
Capital contribution to FPL	(240		)	—			240			—			(310		)	—			310			—
Cash grants under the Recovery Act	—			105			—			105			—			301			202			503
Change in loan proceeds restricted for construction	—			212			—			212			—			(596		)	—			(596		)
Other - net	—			(59		)	(70		)	(129		)	16			4			(32		)	(12		)
Net cash used in investing activities	(240		)	(3,234		)	(3,027		)	(6,501		)	(310		)	(2,241		)	(1,871		)	(4,422		)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	—			3,632			594			4,226			—			2,669			248			2,917
Retirements of long-term debt	—			(1,272		)	(49		)	(1,321		)	—			(1,643		)	(45		)	(1,688		)
Proceeds from sale of differential membership interests	—			414			—			414			—			210			—			210
Net change in short-term debt	—			254			142			396			—			639			307			946
Issuances of common stock	386			—			—			386			39			—			—			39
Dividends on common stock	(752		)	—			—			(752		)	(689		)	—			—			(689		)
Other - net	(56		)	(785		)	705			(136		)	(19		)	(377		)	304			(92		)
Net cash provided by (used in) financing activities	(422		)	2,243			1,392			3,213			(669		)	1,498			814			1,643
Net increase (decrease) in cash and cash equivalents	—			(113		)	(18		)	(131		)	—			328			10			338
Cash and cash equivalents at beginning of period	1			339			37			377			—			282			20			302
Cash and cash equivalents at end of period	$	1		$	226		$	19		$	246		$	—		$	610		$	30		$	640

————————————

(a) Represents FPL and consolidating adjustments.

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) (Parenthetical) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Tax expense (benefit) of unrealized gains/losses on cash flow hedges	$ (15)	$ (92)	$ (41)	$ (125)
Tax expense (benefit) on cash flow hedges reclassified from AOCI to net income	7	10	18	18
Tax expense (benefit) of unrealized gains/losses on available for sale securities still held	18	(27)	44	(12)
Tax expense (benefit) on available for sale securities reclassified from AOCI to net income	(18)	(17)	(43)	(32)
Tax expense (benefit) of defined benefit pension and other benefits plans	0		(3)	4
Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Tax	2	(10)	3	(4)
Other comprehensive income (loss) related to equity method investee, tax	$ (3)		$ (7)

XML

Income Taxes

9 Months Ended

Sep. 30, 2012

Income Tax Disclosure [Abstract]

Income Taxes

5.  Income Taxes

NEE's effective income tax rates for the three months ended September 30, 2012 and 2011 were approximately 27% and 28%, respectively.  The reduction from the federal statutory rate for those respective periods mainly reflects the benefit of wind production tax credits (PTCs) of approximately $35 million and $45 million related to NEER's wind projects and approximately $14 million and $9 million of 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), primarily for certain wind projects expected to be placed in service.

NEE's effective income tax rates for the nine months ended September 30, 2012 and 2011 were approximately 27% and 18%, respectively.  The reduction from the federal statutory rate for those respective periods mainly reflects the benefit of wind PTCs of approximately $147 million and $208 million and approximately $37 million and $17 million of deferred income tax benefits associated with convertible ITCs. NEE's effective income tax rate for the nine months ended September 30, 2011 also reflects a state deferred income tax benefit included in the Corporate and Other segment of approximately $64 million, net of federal income taxes, related to state tax law changes in 2011 (state deferred income tax benefit) and a $26 million reduction in income tax expense, net of federal income taxes, primarily related to a valuation allowance reversal for certain state ITCs reflecting state income tax planning initiatives (state ITC benefit).

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 expiration of PTCs after ten years of production.

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Financial Instruments

9 Months Ended

Sep. 30, 2012

Financial Instruments [Abstract]

Financial Instruments

4.  Financial Instruments

The carrying amounts of cash equivalents and commercial paper approximate their fair values.  At September 30, 2012 and December 31, 2011, other investments of NEE, not included in the table below, included financial instruments of approximately $41 million and $35 million ($8 million and $4 million at FPL), respectively, which primarily consist of notes receivable that are carried at estimated fair value or cost, which approximates fair value.

The following estimates of the fair value of financial instruments have been made primarily using available market information.  However, the use of different market assumptions or methods of valuation could result in different estimated fair values.

	September 30, 2012								December 31, 2011
	Carrying Amount				Estimated Fair Value				Carrying Amount				Estimated Fair Value
	(millions)
NEE:
Special use funds	$	4,223		(a)	$	4,223		(a)	$	3,867		(a)	$	3,867		(a)
Other investments:
Notes receivable	$	500			$	681		(b)	$	503			$	535		(b)
Debt securities	$	115		(c)	$	115		(d)	$	89		(c)	$	89		(d)
Equity securities	$	61			$	75		(e)	$	80			$	159		(e)
Long-term debt, including current maturities	$	24,769			$	27,674		(f)	$	21,614			$	23,699		(f)
Interest rate swaps - net unrealized losses	$	(311	)		$	(311	)	(d)	$	(283	)		$	(283	)	(d)
Foreign currency swaps - net unrealized gains	$	5			$	5		(d)	$	18			$	18		(d)
FPL:
Special use funds	$	2,967		(a)	$	2,967		(a)	$	2,737		(a)	$	2,737		(a)
Long-term debt, including current maturities	$	8,084			$	9,984		(f)	$	7,533			$	9,078		(f)

————————————

(a) At September 30, 2012, includes $229 million of investments accounted for under the equity method and $34 million of loans not measured at fair value on a recurring basis ($144 million and $28 million, respectively, for FPL).  At December 31, 2011, includes $164 million of investments accounted for under the equity method and $39 million of loans not measured at fair value on a recurring basis ($112 million and $24 million, respectively, for FPL).  For the remaining balances, see Note 3 for classification by major security type and hierarchy level.  The amortized cost of debt and equity securities is $1,753 million and $1,437 million, respectively, at September 30, 2012 and $1,638 million and $1,425 million, respectively, at December 31, 2011 ($1,417 million and $791 million, respectively, at September 30, 2012 and $1,321 million and $864 million, respectively, at December 31, 2011 for FPL).

(b) Classified as held to maturity.  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 standings and ratings and market-related information.  As of September 30, 2012, NEE had no notes receivable reported in non-accrual status.

(c) Classified as trading securities.

(d) See Note 3.

(e) Primarily modeled internally based on recent market information including, among other things, private offerings of the securities (Level 3).

(f) As of September 30, 2012 and December 31, 2011, $15,873 million and $15,035 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 consist of FPL's storm fund assets of $127 million and NEE's and FPL's nuclear decommissioning fund assets of $4,096 million and $2,840 million, respectively, at September 30, 2012.  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 (see Note 3).  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 September 30, 2012 of approximately six years at both NEE and FPL.  FPL's storm fund primarily consists of debt securities with a weighted-average maturity at September 30, 2012 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				NEE				FPL
	Three Months Ended September 30,				Three Months Ended September 30,				Nine Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011		2012		2011		2012		2011
	(millions)
Realized gains	$	75	$	69	$	20	$	22	$	206	$	156	$	81	$	60
Realized losses	$	16	$	27	$	12	$	17	$	48	$	70	$	34	$	51
Proceeds from sale or maturity of securities	$	953	$	992	$	592	$	675	$	3,890	$	3,567	$	2,949	$	2,483

Unrealized losses on available for sale debt securities at September 30, 2012 and December 31, 2011 were not material to NEE or FPL.  The unrealized gains on available for sale securities are as follows:

	NEE				FPL
	September 30, 2012		December 31, 2011		September 30, 2012		December 31, 2011
	(millions)
Equity securities	$	694	$	546	$	526	$	376
U.S. Government and municipal bonds	$	32	$	46	$	29	$	43
Corporate debt securities	$	43	$	31	$	32	$	24
Mortgage-backed securities	$	25	$	27	$	22	$	24
Other debt securities	$	2	$	3	$	2	$	3

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.

Interest Rate and Foreign Currency Swaps - NEE and its subsidiaries use a combination of fixed rate and variable rate debt to manage interest rate exposure.  Interest rate swaps are used to mitigate and adjust interest rate exposure when deemed appropriate based upon market conditions or when required by financing agreements.  In addition, with respect to certain debt issuances and borrowings, NEECH has two cross currency swaps to hedge against currency movements with respect to both interest and principal payments.  See Note 2.

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Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2012

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:

	September 30, 2012
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Netting(a)			Total
	(millions)
Assets:
Cash equivalents:
NEE - equity securities	$	22	$	—		$	—	$	—		$	22
FPL - equity securities	$	1	$	—		$	—	$	—		$	1
Special use funds:
NEE:
Equity securities	$	813	$	1,293	(b)	$	—	$	—		$	2,106
U.S. Government and municipal bonds	$	495	$	169		$	—	$	—		$	664
Corporate debt securities	$	—	$	549		$	—	$	—		$	549
Mortgage-backed securities	$	—	$	594		$	—	$	—		$	594
Other debt securities	$	—	$	47		$	—	$	—		$	47
FPL:
Equity securities	$	150	$	1,142	(b)	$	—	$	—		$	1,292
U.S. Government and municipal bonds	$	442	$	132		$	—	$	—		$	574
Corporate debt securities	$	—	$	381		$	—	$	—		$	381
Mortgage-backed securities	$	—	$	513		$	—	$	—		$	513
Other debt securities	$	—	$	35		$	—	$	—		$	35
Other investments:
NEE:
Equity securities	$	12	$	—		$	—	$	—		$	12
U.S. Government and municipal bonds	$	11	$	—		$	—	$	—		$	11
Corporate debt securities	$	—	$	52		$	—	$	—		$	52
Mortgage-backed securities	$	—	$	47		$	—	$	—		$	47
Other	$	5	$	5		$	—	$	—		$	10
Derivatives:
NEE:
Commodity contracts	$	1,407	$	2,605		$	831	$	(3,512	)	$	1,331	(c)
Interest rate swaps	$	—	$	80		$	—	$	—		$	80	(c)
Foreign currency swaps	$	—	$	15		$	—	$	—		$	15	(c)
FPL - commodity contracts	$	—	$	82		$	5	$	(47	)	$	40	(c)
Liabilities:
Derivatives:
NEE:
Commodity contracts	$	1,461	$	2,197		$	349	$	(3,392	)	$	615	(c)
Interest rate swaps	$	—	$	391		$	—	$	—		$	391	(c)
Foreign currency swaps	$	—	$	10		$	—	$	—		$	10	(c)
FPL - commodity contracts	$	—	$	114		$	—	$	(47	)	$	67	(c)

————————————

(a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and margin cash collateral payments and receipts.

(b) At NEE, approximately $1,217 million ($1,093 million at FPL) are invested in commingled funds whose underlying investments would be Level 1 if those investments were held directly by NEE or FPL.

(c) See Note 2 for a reconciliation of net derivatives to NEE's and FPL's condensed consolidated balance sheets.

	December 31, 2011
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Netting(a)			Total
	(millions)
Assets:
Cash equivalents:
NEE - equity securities	$	159	$	—		$	—	$	—		$	159
FPL - equity securities	$	11	$	—		$	—	$	—		$	11
Special use funds:
NEE:
Equity securities	$	709	$	1,206	(b)	$	—	$	—		$	1,915
U.S. Government and municipal bonds	$	508	$	167		$	—	$	—		$	675
Corporate debt securities	$	—	$	516		$	—	$	—		$	516
Mortgage-backed securities	$	—	$	511		$	—	$	—		$	511
Other debt securities	$	—	$	47		$	—	$	—		$	47
FPL:
Equity securities	$	128	$	1,056	(b)	$	—	$	—		$	1,184
U.S. Government and municipal bonds	$	458	$	134		$	—	$	—		$	592
Corporate debt securities	$	—	$	359		$	—	$	—		$	359
Mortgage-backed securities	$	—	$	434		$	—	$	—		$	434
Other debt securities	$	—	$	32		$	—	$	—		$	32
Other investments:
NEE:
Equity securities	$	4	$	—		$	—	$	—		$	4
U.S. Government and municipal bonds	$	8	$	—		$	—	$	—		$	8
Corporate debt securities	$	—	$	43		$	—	$	—		$	43
Mortgage-backed securities	$	—	$	33		$	—	$	—		$	33
Other	$	5	$	5		$	—	$	—		$	10
Derivatives:
NEE:
Commodity contracts	$	2,448	$	3,478		$	1,071	$	(5,477	)	$	1,520	(c)
Interest rate swaps	$	—	$	37		$	—	$	—		$	37	(c)
Foreign currency swaps	$	—	$	27		$	—	$	—		$	27	(c)
FPL - commodity contracts	$	—	$	8		$	6	$	(2	)	$	12	(c)
Liabilities:
Derivatives:
NEE:
Commodity contracts	$	2,588	$	3,582		$	585	$	(5,453	)	$	1,302	(c)
Interest rate swaps	$	—	$	320		$	—	$	—		$	320	(c)
Foreign currency swaps	$	—	$	9		$	—	$	—		$	9	(c)
FPL - commodity contracts	$	—	$	513		$	2	$	(2	)	$	513	(c)

————————————

(a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and margin cash collateral payments and receipts.

(b) At NEE, approximately $1,086 million ($979 million at FPL) are invested in commingled funds whose underlying investments would be Level 1 if those investments were held directly by NEE or FPL.

(c) See Note 2 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 contracts categorized as Level 3 of the fair value hierarchy at September 30, 2012 are as follows:

Transaction Type	Fair Value at September 30, 2012		Valuation Technique(s)	Significant Unobservable Inputs	Range
	Assets	Liabilities
	(millions)
Forward contracts - power	$366	$95	Discounted cash flow	Forward price (per mwh)	$10	–	$141
Options - power	$179	$200	Option models	Implied correlations	12%	—	98%
				Implied volatilities	1%	—	154%
Options - gas	$43	$10	Option models	Implied correlations	12%	—	98%
				Implied volatilities	1%	—	56%
Full requirements and unit contingent contracts	$211	$33	Discounted cash flow	Forward price (per mwh)	$5	—	$127
				Customer migration rate(a)	—%	—	20%

——————————

(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 September 30,
	2012						2011
	NEE			FPL			NEE			FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at June 30	$	575		$	7		$	155		$	5
Realized and unrealized gains (losses):
Included in earnings(a)	(149		)	—			(11		)	—
Included in regulatory assets and liabilities	1			1			—			—
Purchases	40			—			45			—
Settlements	30			(3		)	3			(1		)
Issuances	(21		)	—			(70		)	—
Transfers in(b)	5			—			1			—
Transfers out(b)	1			—			(2		)	—
Fair value of net derivatives based on significant unobservable inputs at September 30	$	482		$	5		$	121		$	4
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)	$	(171	)	$	—		$	12		$	—

————————————

(a) For the three months ended September 30, 2012 and 2011, $(149) million and $(12) million, respectively, of realized and unrealized gains (losses) are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

(b) For the three months ended September 30, 2012 and 2011, 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 September 30, 2012 and 2011, $(170) million and $12 million, respectively, of unrealized gains (losses) are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

	Nine Months Ended September 30,
	2012						2011
	NEE			FPL			NEE			FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year	$	486		$	4		$	296		$	7
Realized and unrealized gains (losses):
Included in earnings(a)	135			—			2			—
Included in regulatory assets and liabilities	7			7			2			2
Purchases	221			—			186			—
Settlements	(152		)	(6		)	(100		)	(5		)
Issuances	(221		)	—			(260		)	—
Transfers in(b)	21			—			3			—
Transfers out(b)	(15		)	—			(8		)	—
Fair value of net derivatives based on significant unobservable inputs at September 30	$	482		$	5		$	121		$	4
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)	$	41		$	—		$	42		$	—

————————————

(a) For the nine months ended September 30, 2012 and 2011, $132 million and $(11) million, respectively, of realized and unrealized gains (losses) are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

(b) For the nine months ended September 30, 2012 and 2011, 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 nine months ended September 30, 2012 and 2011, $41 million and $37 million, respectively, of unrealized gains (losses) 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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Derivative Instruments (Policies)

9 Months Ended

Sep. 30, 2012

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 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 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 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 energy output of these assets.  These hedges protect NEER against adverse changes in the wholesale forward commodity markets associated with its generation 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 customer served by the distribution utility.  For this type of transaction, derivative instruments are used to hedge the anticipated electricity quantities required to serve these customers and protect against 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.  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) or the capacity cost recovery clause (capacity clause).  For NEE's non-rate regulated operations, predominantly NEER, unless hedge accounting is applied, essentially all changes in the derivatives' fair value for power purchases and sales and trading activities are recognized on a net basis in operating revenues; fuel purchases and sales are recognized on a net basis in fuel, purchased power and interchange expense; and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEE's 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.  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.  Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the condensed consolidated statements of income.  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, 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 swaps 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

9 Months Ended

Sep. 30, 2012

Debt Disclosure [Abstract]

Debt

8.  Debt

Long-term debt issuances and borrowings by subsidiaries of NEE during the nine months ended September 30, 2012 were as follows:

Date Issued	Company	Debt Issuances/Borrowings	Interest Rate			Principal Amount		Maturity Date
						(millions)
January - September 2012	NEECH and NEER subsidiary	Canadian revolving credit facilities	Variable		(a)	$	146	2013
January - September 2012	NEER subsidiaries	Euro denominated senior secured limited-recourse loan	Variable		(a)(b)	$	247	2030
January - September 2012	NEER subsidiaries	Euro denominated senior secured limited-recourse loan	Variable		(a)	$	48	2015
January - September 2012	NEECH and NEER subsidiary	Euro denominated revolving loan	Variable		(a)	$	81	2014
January - August 2012	Lone Star Transmission, LLC	Senior secured limited-recourse loan	Variable		(a)	$	150	2016
March 2012	NEECH	Junior subordinated debentures	5.70	%		$	400	2072
May 2012	NEECH	Debentures related to NEE's equity units	1.70	%		$	600	2017
May 2012	FPL	First mortgage bonds	4.05	%		$	600	2042
June 2012	NEECH	Junior subordinated debentures	5.625	%		$	350	2072
July 2012	NEER subsidiary	Limited-recourse term loan	Variable		(a)(b)	$	99	2015
September 2012	NEECH	Debentures related to NEE's equity units	1.60	%		$	650	2017
September 2012	NEECH	Debentures	1.20	%		$	500	2015
September 2012	NEER subsidiary	Canadian senior secured limited-recourse notes	4.881	%		$	176	2031
September 2012	NEER subsidiary	Senior secured limited-recourse loan	Variable		(a)(b)	$	232	2030

————————————

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

(b) Interest rate swap agreements were entered into with respect to these issuances.

In May 2012, NEE sold $600 million of equity units (initially consisting of Corporate Units).  Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series E Debenture due June 1, 2017 issued in the principal amount of $1,000 by NEECH (see table above).  Each stock purchase contract requires the holder to purchase by no later than June 1, 2015 (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range of $64.35 to $77.22.  If purchased on the final settlement date, as of September 30, 2012, the number of shares issued would (subject to antidilution adjustments) range from 0.7770 shares if the applicable market value of a share of common stock is less than or equal to $64.35, to 0.6475 shares if the applicable market value of a share is equal to or greater than $77.22, with applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending May 27, 2015.  Total annual distributions on the equity units will be at the rate of 5.599%, consisting of interest on the debentures (1.70% per year) and payments under the stock purchase contracts (3.899% per year).  The interest rate on the debentures is expected to be reset on or after December 1, 2014.  The holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit.  The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder’s obligation to purchase NEE common stock under the related stock purchase contract.  If a successful remarketing does not occur on or before the third business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE.

Also, in May 2012, a remarketing of $350 million aggregate principal amount of Series C Debentures due June 1, 2014 (Debentures) issued by NEECH was successfully completed.  The Debentures were originally issued in May 2009 as components of NEE's equity units (2009 equity units).  The Debentures are fully and unconditionally guaranteed by NEE.  In connection with the remarketing of the Debentures, the annual interest rate on the Debentures was reset to 1.611% and interest is payable semi-annually on June 1 and December 1, beginning June 1, 2012. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the 2009 equity units, on June 1, 2012, NEE issued 5,400,500 shares of common stock in exchange for $350 million.

In September 2012, NEE sold $650 million of equity units (initially consisting of Corporate Units).  Each equity unit has a stated amount of $50 and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a 5% undivided beneficial ownership interest in a Series F Debenture due September 1, 2017 issued in the principal amount of $1,000 by NEECH (see table above).  Each stock purchase contract requires the holder to purchase by no later than September 1, 2015 (the final settlement date) for a price of $50 in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range of $67.15 to $80.58.  If purchased on the final settlement date, as of September 30, 2012, the number of shares issued would (subject to antidilution adjustments) range from 0.7446 shares if the applicable market value of a share of common stock is less than or equal to $67.15, to 0.6205 shares if the applicable market value of a share is equal to or greater than $80.58, with applicable market value to be determined using the average closing prices of NEE common stock over a 20-day trading period ending August 27, 2015.  Total annual distributions on the equity units will be at the rate of 5.889%, consisting of interest on the debentures (1.60% per year) and payments under the stock purchase contracts (4.289% per year).  The interest rate on the debentures is expected to be reset on or after March 1, 2015.  The holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit.  The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder’s obligation to purchase NEE common stock under the related stock purchase contract.  If a successful remarketing does not occur on or before the third business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE.

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Variable Interest Entities (VIEs)

9 Months Ended

Sep. 30, 2012

Variable Interest Entities [Abstract]

Variable Interest Entities (VIEs)

6.  Variable Interest Entities (VIEs)

As of September 30, 2012, NEE has ten 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 $356 million and $406 million at September 30, 2012 and December 31, 2011, 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 $441 million and $496 million at September 30, 2012 and December 31, 2011, 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 (PPA) effective in 1994 with this 250 megawatt (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 PPA 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 passed on to FPL's customers 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 September 30, 2012 and 2011, FPL purchased 293,650 mwh and 327,583 mwh, respectively, from the facility at a total cost of approximately $48 million and $50 million, respectively. During the nine months ended September 30, 2012 and 2011, FPL purchased 582,661 mwh and 965,105 mwh, respectively, from the facility at a total cost of approximately $133 million and $144 million, respectively.

Additionally, FPL entered into a PPA 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 passed on to FPL’s customers through the fuel clause as approved by the FPSC.

NEER - NEE consolidates nine 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.

An 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. The assets and liabilities of the VIE were approximately $96 million and $74 million, respectively, at September 30, 2012 and $105 million and $82 million, respectively, at December 31, 2011, and consisted primarily of property, plant and equipment and long-term debt.

The other eight NEER VIEs consolidate several entities which own and operate wind electric generating facilities with the capability of producing a total of 2,658 mw.  Seven of these VIEs sell their electric output under power sales contracts to third parties with expiration dates ranging from 2018 through 2037; the eighth VIE sells its 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.  The debt holders have no recourse to the general credit of NEER.  The assets and liabilities of these VIEs totaled approximately $4.1 billion and $2.8 billion, respectively, at September 30, 2012. Six of the eight were VIEs at December 31, 2011 and were consolidated; the assets and liabilities of those VIEs totaled approximately $3.2 billion and $2.6 billion, respectively, at December 31, 2011. At September 30, 2012 and December 31, 2011, 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 September 30, 2012 and December 31, 2011, several NEE subsidiaries have investments totaling approximately $784 million ($619 million at FPL) and $668 million ($526 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 September 30, 2012, 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 Stock

9 Months Ended

Sep. 30, 2012

Equity [Abstract]

Common Stock

7.  Common Stock

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
	(millions, except per share amounts)
Numerator - net income	$	415	$	407	$	1,482	$	1,256
Denominator:
Weighted-average number of common shares outstanding - basic	419.3		417.4		415.6		416.7
Performance share awards, options, restricted stock and equity units(a)	2.4		2.4		2.4		2.4
Weighted-average number of common shares outstanding - assuming dilution	421.7		419.8		418.0		419.1
Earnings per share of common stock:
Basic	$	0.99	$	0.98	$	3.57	$	3.01
Assuming dilution	$	0.98	$	0.97	$	3.55	$	3.00

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(a) 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.  Performance share awards, options, restricted stock and equity units are included in diluted weighted-average number of common shares outstanding by applying the treasury stock method.

Common shares issuable pursuant to equity units and stock options, performance shares and restricted stock awards which were not included in the denominator above due to their antidilutive effect were approximately 3.2 million and 14.6 million for the three months ended September 30, 2012 and 2011, respectively, and 9.9 million and 14.5 million for the nine months ended September 30, 2012 and 2011, respectively.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2012

Commitments and Contingencies [Abstract]

Commitments and Contingencies

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 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 transmission line and other associated facilities by Lone Star Transmission, LLC (Lone Star), a rate-regulated transmission service provider in Texas, and the cost to meet customer-specific requirements and maintain the fiber-optic network for the fiber-optic telecommunications business (FPL FiberNet).

At September 30, 2012, estimated capital expenditures for the remainder of 2012 through 2016 were as follows:

	Remainder of 2012		2013		2014		2015		2016		Total
	(millions)
FPL:
Generation:(a)
New(b)(c)	$	500	$	770	$	770	$	295	$	120	$	2,455
Existing	190		645		655		550		440		2,480
Transmission and distribution	215		690		690		660		705		2,960
Nuclear fuel	70		125		205		245		245		890
General and other	45		190		120		80		85		520
Total	$	1,020	$	2,420	$	2,440	$	1,830	$	1,595	$	9,305
NEER:
Wind(d)	$	740	$	285	$	25	$	5	$	5	$	1,060
Solar(e)	390		670		160		5		—		1,225
Nuclear(f)	95		315		280		285		325		1,300
Other(g)	85		200		120		135		60		600
Total	$	1,310	$	1,470	$	585	$	430	$	390	$	4,185
Corporate and Other(h)	$	115	$	115	$	45	$	45	$	45	$	365

————————————

(a) Includes allowance for funds used during construction (AFUDC) of approximately $24 million, $82 million, $53 million, $48 million and $27 million in 2012 to 2016, respectively.

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

(c) Consists of projects that have received FPSC approval.  Includes pre-construction costs and carrying charges (equal to a pretax AFUDC rate) on construction costs recoverable through the capacity clause of approximately $24 million, $42 million and $12 million in 2012 to 2014, respectively.  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) Consists of capital expenditures for planned new wind projects and related transmission totaling approximately 1,500 mw, including approximately 150 mw in Canada, that have received applicable internal approvals.  Excludes new Canadian wind projects requiring internal approvals with generation totaling approximately 470 mw in 2014 and 2015, with an estimated cost of approximately $1.3 billion to $1.5 billion.

(e) Consists of capital expenditures for planned new solar projects and related transmission totaling 625 mw that have received applicable internal approvals, including equity contributions associated with a 50% equity method investment in a 550 mw solar project.  Excludes solar projects requiring internal approvals with generation totaling 270 mw with an estimated cost of approximately $600 million to $800 million.

(f) Includes nuclear fuel.

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

(h) Consists of capital expenditures that have received applicable internal approvals and includes AFUDC of approximately $9 million and $14 million in 2012 and 2013, respectively.

These estimates are subject to continuing review and adjustment and actual capital expenditures may vary significantly from these estimates.

Contracts - In addition to the estimated capital expenditures included in the table in Commitments above, FPL has commitments under long-term purchased power and fuel contracts.  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.

NEER has entered into contracts primarily for the purchase of wind turbines and towers, solar reflectors, steam turbine generators and heat collection elements and related construction and development activities, as well as for the supply of uranium, conversion, enrichment and fabrication of nuclear fuel, with expiration dates ranging from December 2012 through 2030, approximately $1.7 billion of which is 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 December 2012 through 2033.

The transmission business included in Corporate and Other has entered into contracts primarily for development and construction activities relating to Lone Star's transmission line and other associated facilities, all of which is included in the estimated capital expenditures table in Commitments above.

The required capacity and/or minimum payments under the contracts discussed above as of September 30, 2012 were estimated as follows:

	Remainder of 2012		2013		2014		2015		2016		Thereafter
	(millions)
FPL:
Capacity charges:(a)
Qualifying facilities	$	75	$	270	$	275	$	280	$	245	$	2,415
JEA and Southern subsidiaries	$	60	$	230	$	220	$	195	$	70	$	155
Minimum charges, at projected prices:
Natural gas, including transportation and storage(b)	$	495	$	1,580	$	1,065	$	570	$	535	$	6,935
Coal(b)	$	25	$	90	$	35	$	5	$	5	$	—
NEER	$	610	$	690	$	235	$	85	$	105	$	600
Corporate and Other(c)	$	65	$	30	$	10	$	15	$	15	$	20

————————————

(a) Capacity charges under these contracts, substantially all of which are recoverable through the capacity clause, totaled approximately $129 million and $128 million for the three months ended September 30, 2012 and 2011, respectively, and approximately $391 million and $383 million for the nine months ended September 30, 2012 and 2011, respectively. Energy charges under these contracts, which are recoverable through the fuel clause, totaled approximately $110 million and $135 million for the three months ended September 30, 2012 and 2011, respectively, and approximately $232 million and $348 million for the nine months ended September 30, 2012 and 2011, respectively.

(b) Recoverable through the fuel clause.

(c) Includes an approximately $68 million commitment to invest in clean power and technology businesses through 2017.

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 $12.2 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 $940 million ($470 million for FPL), plus any applicable taxes, per incident at any nuclear reactor in the United States, payable at a rate not to exceed $140 million ($70 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 $14 million, $35 million and $18 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.  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 $178 million ($102 million for FPL), plus any applicable taxes, in retrospective premiums in a policy year.  NEE and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook, Duane Arnold and St. Lucie Unit No. 2, which approximates $2 million, $4 million and $4 million, plus any applicable taxes, respectively.

Due to the high cost and limited coverage available from third-party insurers, NEE does not have insurance coverage for a substantial portion of its transmission and distribution property and has no 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, would be borne by NEE and FPL and could have a material adverse effect on NEE's and FPL's financial condition, results of operations and liquidity.

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 a 76% interest, 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 October 2004, TXU Portfolio Management Company (TXU) served FPL Energy Pecos Wind I, LP, FPL Energy Pecos Wind I GP, LLC, FPL Energy Pecos Wind II, LP, FPL Energy Pecos Wind II GP, LLC and Indian Mesa Wind Farm, LP (NEER Affiliates) as defendants in a civil action filed in the District Court in Dallas County, Texas.  FPL Energy, LLC, now known as NextEra Energy Resources, LLC, was added as a defendant in 2005.  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.  The plaintiff 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, among other findings, both TXU and the NEER Affiliates were found to have breached the contracts.  In August 2008, the trial court issued a final judgment holding that the contracts were not terminated and neither party was entitled to recover any damages.  In November 2008, TXU appealed the final judgment to the Fifth District Court of Appeals in Dallas, Texas.  In an opinion issued in July 2010, the appellate court reversed portions of the trial court's judgment, ruling that the contracts' liquidated damage provision is an enforceable liquidated damage clause.  The appellate court ordered that the case be remanded back to the trial court for further proceedings to determine the amount of damages payable by the NEER Affiliates.  The NEER Affiliates filed a motion for rehearing of the appellate court’s decision, which motion was denied, and in April 2011 filed a petition for review of the appellate court decision with the Texas Supreme Court.  In February 2012, the Texas Supreme Court granted the petition for review and oral arguments were heard in October 2012.

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 NEE or FPL has an ownership interest are also involved in legal and regulatory proceedings, actions and claims, the liabilities from which, if any, would be shared by NEE or FPL.  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 (Net Notional Volumes and Additional Disclosures) (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012 megawatt-hours
Commodity contract - Power [Member]
Derivative [Line Items]
Non-monetary net notional volumes	(46,000,000)
Commodity contract - Natural gas [Member]
Derivative [Line Items]
Non-monetary net notional volumes	1,221,000,000
Commodity contract - Oil [Member]
Derivative [Line Items]
Non-monetary net notional volumes	(7,000,000)
Interest rate swaps [Member]
Derivative [Line Items]
Notional amount	6,900
Currency Swap [Member]
Derivative [Line Items]
Notional amount	544
FPL [Member] | Commodity contract - Power [Member]
Derivative [Line Items]
Non-monetary net notional volumes	0
FPL [Member] | Commodity contract - Natural gas [Member]
Derivative [Line Items]
Non-monetary net notional volumes	837,000,000
FPL [Member] | Commodity contract - Oil [Member]
Derivative [Line Items]
Non-monetary net notional volumes	0

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Employee Retirement Benefits (Tables)

9 Months Ended

Sep. 30, 2012

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						Pension Benefits						Other Benefits
	Three Months Ended September 30,						Three Months Ended September 30,						Nine Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011			2012			2011			2012			2011
	(millions)
Service cost	$	16		$	16		$	1		$	2		$	49		$	48		$	4		$	5
Interest cost	25			25			4			5			74			74			13			16
Expected return on plan assets	(60		)	(60		)	—			(1		)	(179		)	(179		)	(1		)	(2		)
Amortization of transition obligation	—			—			—			1			—			—			1			2
Amortization of prior service cost (benefit)	1			(1		)	(1		)	—			3			(2		)	—			—
Net periodic benefit (income) cost at NEE	$	(18	)	$	(20	)	$	4		$	7		$	(53	)	$	(59	)	$	17		$	21
Net periodic benefit (income) cost at FPL	$	(11	)	$	(13	)	$	3		$	5		$	(34	)	$	(39	)	$	13		$	16

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Debt (Tables)

9 Months Ended

Sep. 30, 2012

Debt Disclosure [Abstract]

Long-term debt issuances and borrowings

Long-term debt issuances and borrowings by subsidiaries of NEE during the nine months ended September 30, 2012 were as follows:

Date Issued	Company	Debt Issuances/Borrowings	Interest Rate			Principal Amount		Maturity Date
						(millions)
January - September 2012	NEECH and NEER subsidiary	Canadian revolving credit facilities	Variable		(a)	$	146	2013
January - September 2012	NEER subsidiaries	Euro denominated senior secured limited-recourse loan	Variable		(a)(b)	$	247	2030
January - September 2012	NEER subsidiaries	Euro denominated senior secured limited-recourse loan	Variable		(a)	$	48	2015
January - September 2012	NEECH and NEER subsidiary	Euro denominated revolving loan	Variable		(a)	$	81	2014
January - August 2012	Lone Star Transmission, LLC	Senior secured limited-recourse loan	Variable		(a)	$	150	2016
March 2012	NEECH	Junior subordinated debentures	5.70	%		$	400	2072
May 2012	NEECH	Debentures related to NEE's equity units	1.70	%		$	600	2017
May 2012	FPL	First mortgage bonds	4.05	%		$	600	2042
June 2012	NEECH	Junior subordinated debentures	5.625	%		$	350	2072
July 2012	NEER subsidiary	Limited-recourse term loan	Variable		(a)(b)	$	99	2015
September 2012	NEECH	Debentures related to NEE's equity units	1.60	%		$	650	2017
September 2012	NEECH	Debentures	1.20	%		$	500	2015
September 2012	NEER subsidiary	Canadian senior secured limited-recourse notes	4.881	%		$	176	2031
September 2012	NEER subsidiary	Senior secured limited-recourse loan	Variable		(a)(b)	$	232	2030

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

(b) Interest rate swap agreements were entered into with respect to these issuances.

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Segment Information (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2012		Sep. 30, 2011		Sep. 30, 2012		Sep. 30, 2011		Dec. 31, 2011
Segment Reporting Information [Line Items]
OPERATING REVENUE	$ 3,843		$ 4,382		$ 10,881		$ 11,476
Operating revenues	3,843		4,382		10,881		11,476
Operating expenses	3,094		3,471		8,266		9,230
Net income (loss)	415		407		1,482		1,256
Total assets	62,049				62,049				57,188
Deemed capital structure of NextEra Energy Resources	70.00%				70.00%
Loss on natural gas-fired generating assets held for sale	0		148		0		148
Impairment charges	0		0		0		51
Impairment Of Long Lived Assets Held For Use After Tax							31
Deferred state tax benefit related to recent state tax law changes							64
FPL [Member]
Segment Reporting Information [Line Items]
OPERATING REVENUE	2,975		3,152
Operating revenues					7,778		8,200
Operating expenses	2,256		2,496		5,916		6,566
Net income (loss)	392		347		984		852
Total assets	34,120				34,120				31,816
NextEra Energy Resources [Member]
Segment Reporting Information [Line Items]
Operating revenues	808	[1]	1,172	[1]	2,929	[1]	3,110	[1]
Operating expenses	785	[1]	920	[1]	2,201	[1]	2,520	[1],[2]
Net income (loss)	44	[1],[3]	67	[1],[3]	516	[1],[3]	371	[1],[3],[4]
Total assets	25,761				25,761				23,459
Loss on natural gas-fired generating assets held for sale							91
Impairment Of Long Lived Assets Held For Use After Tax							31
Corporate and Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	60		58		174		166
Operating expenses	53		55		149		144
Net income (loss)	(21)		(7)	[5]	(18)		33	[5],[6]
Total assets	2,168				2,168				1,913
Loss on natural gas-fired generating assets held for sale							6
FPL [Member]
Segment Reporting Information [Line Items]
OPERATING REVENUE	2,975		3,152		7,778		8,200
Operating expenses	2,256		2,496		5,916		6,566
Net income (loss)	392		347		984		852
Total assets	$ 34,120				$ 34,120				$ 31,816

[1] 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.

[2] Includes impairment charges of approximately $51 million. See Note 3 - Nonrecurring Fair Value Measurements.

[3] See Note 5 for a discussion of NEER's tax benefits related to PTCs. 2011 includes after-tax loss on natural gas-fired generating assets held for sale of $91 million. See Note 3 - Nonrecurring Fair Value Measurements.

[4] Includes after-tax impairment charges of approximately $31 million. See Note 3 - Nonrecurring Fair Value Measurements.

[5] Includes after-tax loss on natural gas-fired generating assets held for sale of $6 million. See Note 3 - Nonrecurring Fair Value Measurements.

[6] Includes the state deferred income tax benefit of approximately $64 million. See Note 5.

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Financial Instruments, Available For Sale Securities (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended												3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012 Available For Sale Securities: Special Use Funds - Equity Securities [Member]	Dec. 31, 2011 Available For Sale Securities: Special Use Funds - Equity Securities [Member]	Sep. 30, 2012 Available For Sale Securities: Special Use Funds - U.S. Government And Municipal Bonds [Member]	Dec. 31, 2011 Available For Sale Securities: Special Use Funds - U.S. Government And Municipal Bonds [Member]	Sep. 30, 2012 Available For Sale Securities: Special Use Funds - Corporate Debt Securities [Member]	Dec. 31, 2011 Available For Sale Securities: Special Use Funds - Corporate Debt Securities [Member]	Sep. 30, 2012 Available For Sale Securities: Special Use Funds - Mortgage-Backed Securities [Member]	Dec. 31, 2011 Available For Sale Securities: Special Use Funds - Mortgage-Backed Securities [Member]	Sep. 30, 2012 Available For Sale Securities: Special Use Funds - Other Debt Securities [Member]	Dec. 31, 2011 Available For Sale Securities: Special Use Funds - Other Debt Securities [Member]	Sep. 30, 2012 FPL [Member]	Sep. 30, 2011 FPL [Member]	Sep. 30, 2012 FPL [Member]	Sep. 30, 2011 FPL [Member]	Sep. 30, 2012 FPL [Member] Available For Sale Securities: Special Use Funds - Equity Securities [Member]	Dec. 31, 2011 FPL [Member] Available For Sale Securities: Special Use Funds - Equity Securities [Member]	Sep. 30, 2012 FPL [Member] Available For Sale Securities: Special Use Funds - U.S. Government And Municipal Bonds [Member]	Dec. 31, 2011 FPL [Member] Available For Sale Securities: Special Use Funds - U.S. Government And Municipal Bonds [Member]	Sep. 30, 2012 FPL [Member] Available For Sale Securities: Special Use Funds - Corporate Debt Securities [Member]	Dec. 31, 2011 FPL [Member] Available For Sale Securities: Special Use Funds - Corporate Debt Securities [Member]	Sep. 30, 2012 FPL [Member] Available For Sale Securities: Special Use Funds - Mortgage-Backed Securities [Member]	Dec. 31, 2011 FPL [Member] Available For Sale Securities: Special Use Funds - Mortgage-Backed Securities [Member]	Sep. 30, 2012 FPL [Member] Available For Sale Securities: Special Use Funds - Other Debt Securities [Member]	Dec. 31, 2011 FPL [Member] Available For Sale Securities: Special Use Funds - Other Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale Securities, Gross Realized Gains	$ 75	$ 69	$ 206	$ 156											$ 20	$ 22	$ 81	$ 60
Available-for-sale Securities, Gross Realized Losses	16	27	48	70											12	17	34	51
Available For Sale Securities Gross Unrealized Gains Abstract
Unrealized gains					694	546	32	46	43	31	25	27	2	3					526	376	29	43	32	24	22	24	2	3
Proceeds from Sale and Maturity of Available-for-sale Securities	$ 953	$ 992	$ 3,890	$ 3,567											$ 592	$ 675	$ 2,949	$ 2,483

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CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012		Dec. 31, 2011
PROPERTY, PLANT AND EQUIPMENT
Electric utility plant in service and other property	$ 54,262		$ 50,768
Nuclear fuel	1,994		1,795
Construction work in progress	7,174		4,989
Less accumulated depreciation and amortization	(15,737)		(15,062)
Total property, plant and equipment - net	47,693		42,490
CURRENT ASSETS
Cash and cash equivalents	246		377
Customer receivables, net of allowances	1,633		1,372
Other receivables	489		430
Materials, supplies and fossil fuel inventory	1,055		1,074
Regulatory assets:
Deferred clause and franchise expenses	54		112
Derivatives	59		502
Other	87		84
Derivatives	482		611
Other	332		310
Total current assets	4,437		4,872
OTHER ASSETS
Special use funds	4,223		3,867
Other investments	971		907
Prepaid benefit costs	1,093		1,021
Regulatory assets:
Securitized storm-recovery costs	462		517
Other	524		621
Derivatives	944	[1]	973	[1]
Other	1,702		1,920
Total other assets	9,919		9,826
TOTAL ASSETS	62,049		57,188
CAPITALIZATION
Common stock	4		4
Additional paid-in capital	5,494		5,217
Retained earnings	10,607		9,876
Accumulated other comprehensive income (loss)	(219)		(154)
Total common shareholders' equity	15,886		14,943
Long-term debt	22,714		20,810
Total capitalization	38,600		35,753
CURRENT LIABILITIES
Commercial paper	1,053		1,349
Short-term debt	521		0
Current maturities of long-term debt	2,062		808
Accounts payable	1,194		1,191
Customer deposits	513		547
Accrued interest and taxes	703		464
Derivatives	486	[2]	1,090	[2]
Accrued construction-related expenditures	512		518
Other	831		752
Total current liabilities	7,875		6,719
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,685		1,611
Accumulated deferred income taxes	6,166		5,681
Regulatory liabilities:
Accrued asset removal costs	2,017		2,197
Asset retirement obligation regulatory expense difference	1,814		1,640
Other	361		419
Derivatives	530	[3]	541	[3]
Deferral related to differential membership interests - VIEs	1,498		1,203
Other	1,503		1,424
Total other liabilities and deferred credits	15,574		14,716
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	62,049		57,188
FPL [Member]
ELECTRIC UTILITY PLANT
Plant in service and other property	33,981		31,564
Nuclear fuel	1,148		1,005
Construction work in progress	2,492		2,601
Less accumulated depreciation and amortization	(10,915)		(10,916)
Electric utility plant - net	26,706		24,254
CURRENT ASSETS
Cash and cash equivalents	20		36
Customer receivables, net of allowances	986		682
Other receivables	239		312
Materials, supplies and fossil fuel inventory	736		759
Regulatory assets:
Deferred clause and franchise expenses	54		112
Derivatives	59		502
Other	83		80
Other	132		166
Total current assets	2,309		2,649
OTHER ASSETS
Special use funds	2,967		2,737
Prepaid benefit costs	1,124		1,088
Regulatory assets:
Securitized storm-recovery costs	462		517
Other	336		395
Derivatives	32	[1],[4]	2	[1],[4]
Other	216		176
Total other assets	5,105		4,913
TOTAL ASSETS	34,120		31,816
CAPITALIZATION
Common stock	1,373		1,373
Additional paid-in capital	5,703		5,464
Retained earnings	4,998		4,013
Total common shareholders' equity	12,074		10,850
Long-term debt	7,632		7,483
Total capitalization	19,706		18,333
CURRENT LIABILITIES
Commercial paper	472		330
Current maturities of long-term debt	452		50
Accounts payable	672		678
Customer deposits	508		541
Accrued interest and taxes	486		221
Derivatives	67	[2]	512	[2]
Accrued construction-related expenditures	210		261
Other	384		373
Total current liabilities	3,251		2,966
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations	1,190		1,144
Accumulated deferred income taxes	5,248		4,593
Regulatory liabilities:
Accrued asset removal costs	2,017		2,197
Asset retirement obligation regulatory expense difference	1,814		1,640
Other	361		416
Derivatives	0	[3],[5]	1	[3],[5]
Other	533		527
Total other liabilities and deferred credits	11,163		10,517
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$ 34,120		$ 31,816

[1] At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $154 million and $109 million (none at FPL), respectively, in margin cash collateral received from counterparties.

[2] At September 30, 2012 and December 31, 2011, NEE's balances reflect the netting of approximately $74 million and $112 million (none at FPL), respectively, in margin cash collateral provided to counterparties.

[3] At December 31, 2011, NEE's balance reflects the netting of approximately $79 million (none at FPL) in margin cash collateral provided to counterparties.

[4] Included in noncurrent other assets on FPL's condensed consolidated balance sheets.

[5] Included in noncurrent other liabilities on FPL's condensed consolidated balance sheets.

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Fair Value Measurements

9 Months Ended

Sep. 30, 2012

Fair Value Disclosures [Abstract]

Fair Value Measurements

3.  Fair Value Measurements

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 and FPL primarily hold 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 significant other observable inputs.

NEE and FPL also enter 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.  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, through NEER, also enters into full requirements contracts, which, in many 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.  This consideration includes, but is not limited to, assumptions about market liquidity, volatility and contract duration as more fully described below in Significant Unobservable Inputs.

NEE uses interest rate and foreign currency swaps to mitigate and adjust interest rate and foreign currency exposure related to certain outstanding and forecasted debt issuances and borrowings.  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 swap 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:

	September 30, 2012
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Netting(a)			Total
	(millions)
Assets:
Cash equivalents:
NEE - equity securities	$	22	$	—		$	—	$	—		$	22
FPL - equity securities	$	1	$	—		$	—	$	—		$	1
Special use funds:
NEE:
Equity securities	$	813	$	1,293	(b)	$	—	$	—		$	2,106
U.S. Government and municipal bonds	$	495	$	169		$	—	$	—		$	664
Corporate debt securities	$	—	$	549		$	—	$	—		$	549
Mortgage-backed securities	$	—	$	594		$	—	$	—		$	594
Other debt securities	$	—	$	47		$	—	$	—		$	47
FPL:
Equity securities	$	150	$	1,142	(b)	$	—	$	—		$	1,292
U.S. Government and municipal bonds	$	442	$	132		$	—	$	—		$	574
Corporate debt securities	$	—	$	381		$	—	$	—		$	381
Mortgage-backed securities	$	—	$	513		$	—	$	—		$	513
Other debt securities	$	—	$	35		$	—	$	—		$	35
Other investments:
NEE:
Equity securities	$	12	$	—		$	—	$	—		$	12
U.S. Government and municipal bonds	$	11	$	—		$	—	$	—		$	11
Corporate debt securities	$	—	$	52		$	—	$	—		$	52
Mortgage-backed securities	$	—	$	47		$	—	$	—		$	47
Other	$	5	$	5		$	—	$	—		$	10
Derivatives:
NEE:
Commodity contracts	$	1,407	$	2,605		$	831	$	(3,512	)	$	1,331	(c)
Interest rate swaps	$	—	$	80		$	—	$	—		$	80	(c)
Foreign currency swaps	$	—	$	15		$	—	$	—		$	15	(c)
FPL - commodity contracts	$	—	$	82		$	5	$	(47	)	$	40	(c)
Liabilities:
Derivatives:
NEE:
Commodity contracts	$	1,461	$	2,197		$	349	$	(3,392	)	$	615	(c)
Interest rate swaps	$	—	$	391		$	—	$	—		$	391	(c)
Foreign currency swaps	$	—	$	10		$	—	$	—		$	10	(c)
FPL - commodity contracts	$	—	$	114		$	—	$	(47	)	$	67	(c)

————————————

(a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and margin cash collateral payments and receipts.

(b) At NEE, approximately $1,217 million ($1,093 million at FPL) are invested in commingled funds whose underlying investments would be Level 1 if those investments were held directly by NEE or FPL.

(c) See Note 2 for a reconciliation of net derivatives to NEE's and FPL's condensed consolidated balance sheets.

	December 31, 2011
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Netting(a)			Total
	(millions)
Assets:
Cash equivalents:
NEE - equity securities	$	159	$	—		$	—	$	—		$	159
FPL - equity securities	$	11	$	—		$	—	$	—		$	11
Special use funds:
NEE:
Equity securities	$	709	$	1,206	(b)	$	—	$	—		$	1,915
U.S. Government and municipal bonds	$	508	$	167		$	—	$	—		$	675
Corporate debt securities	$	—	$	516		$	—	$	—		$	516
Mortgage-backed securities	$	—	$	511		$	—	$	—		$	511
Other debt securities	$	—	$	47		$	—	$	—		$	47
FPL:
Equity securities	$	128	$	1,056	(b)	$	—	$	—		$	1,184
U.S. Government and municipal bonds	$	458	$	134		$	—	$	—		$	592
Corporate debt securities	$	—	$	359		$	—	$	—		$	359
Mortgage-backed securities	$	—	$	434		$	—	$	—		$	434
Other debt securities	$	—	$	32		$	—	$	—		$	32
Other investments:
NEE:
Equity securities	$	4	$	—		$	—	$	—		$	4
U.S. Government and municipal bonds	$	8	$	—		$	—	$	—		$	8
Corporate debt securities	$	—	$	43		$	—	$	—		$	43
Mortgage-backed securities	$	—	$	33		$	—	$	—		$	33
Other	$	5	$	5		$	—	$	—		$	10
Derivatives:
NEE:
Commodity contracts	$	2,448	$	3,478		$	1,071	$	(5,477	)	$	1,520	(c)
Interest rate swaps	$	—	$	37		$	—	$	—		$	37	(c)
Foreign currency swaps	$	—	$	27		$	—	$	—		$	27	(c)
FPL - commodity contracts	$	—	$	8		$	6	$	(2	)	$	12	(c)
Liabilities:
Derivatives:
NEE:
Commodity contracts	$	2,588	$	3,582		$	585	$	(5,453	)	$	1,302	(c)
Interest rate swaps	$	—	$	320		$	—	$	—		$	320	(c)
Foreign currency swaps	$	—	$	9		$	—	$	—		$	9	(c)
FPL - commodity contracts	$	—	$	513		$	2	$	(2	)	$	513	(c)

————————————

(a) Includes the effect of the contractual ability to settle contracts under master netting arrangements and margin cash collateral payments and receipts.

(b) At NEE, approximately $1,086 million ($979 million at FPL) are invested in commingled funds whose underlying investments would be Level 1 if those investments were held directly by NEE or FPL.

(c) See Note 2 for a reconciliation of net derivatives to NEE's and FPL's condensed consolidated balance sheets.

Significant Unobservable Inputs - 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 Risk Management group.  The Risk Management group performs a risk management function within NEE and FPL 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 Risk Management group is separate from the transacting group, and the Vice President of Risk Management reports to the Chief Financial Officer of NEE and FPL.  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 Vice President of Risk Management.  In addition, other valuation assumptions such as implied correlations and customer migration rates are reviewed and approved by Risk Management on a periodic basis.  Newly created models used in the valuation process are also subject to testing and approval by Risk Management prior to use and established models are reviewed annually, or more often as needed, by Risk Management.

On a monthly basis, the Exposure Management Committee (EMC), which is comprised of certain members of senior management, meets with representatives from the 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 Risk Management policy.  The EMC executes its risk management responsibilities through direct oversight and delegation of its responsibilities to the Vice President of Risk Management, as well as to other corporate and business unit personnel.

The significant unobservable inputs used in the valuation of contracts categorized as Level 3 of the fair value hierarchy at September 30, 2012 are as follows:

Transaction Type	Fair Value at September 30, 2012		Valuation Technique(s)	Significant Unobservable Inputs	Range
	Assets	Liabilities
	(millions)
Forward contracts - power	$366	$95	Discounted cash flow	Forward price (per mwh)	$10	–	$141
Options - power	$179	$200	Option models	Implied correlations	12%	—	98%
				Implied volatilities	1%	—	154%
Options - gas	$43	$10	Option models	Implied correlations	12%	—	98%
				Implied volatilities	1%	—	56%
Full requirements and unit contingent contracts	$211	$33	Discounted cash flow	Forward price (per mwh)	$5	—	$127
				Customer migration rate(a)	—%	—	20%

——————————

(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	Increase (decrease)
	Sell power	Decrease (increase)
Implied correlations	Purchase option	Decrease (increase)
	Sell option	Increase (decrease)
Implied volatilities	Purchase option	Increase (decrease)
	Sell option	Decrease (increase)
Customer migration rate	Sell power(a)	Decrease (increase)

————————————

(a) Assumes the contract is in a gain position.

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

	Three Months Ended September 30,
	2012						2011
	NEE			FPL			NEE			FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at June 30	$	575		$	7		$	155		$	5
Realized and unrealized gains (losses):
Included in earnings(a)	(149		)	—			(11		)	—
Included in regulatory assets and liabilities	1			1			—			—
Purchases	40			—			45			—
Settlements	30			(3		)	3			(1		)
Issuances	(21		)	—			(70		)	—
Transfers in(b)	5			—			1			—
Transfers out(b)	1			—			(2		)	—
Fair value of net derivatives based on significant unobservable inputs at September 30	$	482		$	5		$	121		$	4
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)	$	(171	)	$	—		$	12		$	—

————————————

(a) For the three months ended September 30, 2012 and 2011, $(149) million and $(12) million, respectively, of realized and unrealized gains (losses) are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

(b) For the three months ended September 30, 2012 and 2011, 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 September 30, 2012 and 2011, $(170) million and $12 million, respectively, of unrealized gains (losses) are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

	Nine Months Ended September 30,
	2012						2011
	NEE			FPL			NEE			FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year	$	486		$	4		$	296		$	7
Realized and unrealized gains (losses):
Included in earnings(a)	135			—			2			—
Included in regulatory assets and liabilities	7			7			2			2
Purchases	221			—			186			—
Settlements	(152		)	(6		)	(100		)	(5		)
Issuances	(221		)	—			(260		)	—
Transfers in(b)	21			—			3			—
Transfers out(b)	(15		)	—			(8		)	—
Fair value of net derivatives based on significant unobservable inputs at September 30	$	482		$	5		$	121		$	4
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)	$	41		$	—		$	42		$	—

————————————

(a) For the nine months ended September 30, 2012 and 2011, $132 million and $(11) million, respectively, of realized and unrealized gains (losses) are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

(b) For the nine months ended September 30, 2012 and 2011, 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 nine months ended September 30, 2012 and 2011, $41 million and $37 million, respectively, of unrealized gains (losses) 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 the second quarter of 2011, market value indications and the potential impact of proposed environmental regulations suggested that the carrying value of certain NEER assets, primarily wind assets in West Texas and oil-fired assets in Maine, could be impaired.  NEER performed a fair value analysis and concluded that an impairment charge related to the long-lived assets, primarily property, plant and equipment, was necessary.  The fair value analysis was primarily based on the income approach using significant unobservable inputs (Level 3) including revenue and generation forecasts, projected capital and maintenance expenditures and discount rates.  As a result, long-lived assets held and used with a carrying amount of approximately $79 million were written down to their fair value of $28 million, resulting in an impairment charge of $51 million ($31 million after-tax), which is recorded as a separate line item in NEE’s condensed consolidated statements of income for the nine months ended September 30, 2011.

In the third quarter of 2011, a subsidiary of NEER entered into an agreement to sell its ownership interest in four natural gas-fired generating plants with a total generating capacity of 2,152 mw. In connection with the agreement to sell, during the three and nine months ended September 30, 2011, a loss of approximately $148 million ($97 million after-tax) was recorded in NEE's condensed consolidated statements of income consisting of the impact of writing down the net natural gas-fired generating assets held for sale to their estimated fair value less costs to sell and the reclassification of $30 million from AOCI as a result of the discontinuance of certain cash flow hedges because it became no longer probable that the future hedged transactions would occur. See Note 2. The sale of the four natural gas-fired plants discussed above and the sale of one additional natural gas-fired plant were completed in the fourth quarter of 2011.

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Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2012

Commitments and Contingencies [Abstract]

Schedule of Planned Capital Expenditures

At September 30, 2012, estimated capital expenditures for the remainder of 2012 through 2016 were as follows:

	Remainder of 2012		2013		2014		2015		2016		Total
	(millions)
FPL:
Generation:(a)
New(b)(c)	$	500	$	770	$	770	$	295	$	120	$	2,455
Existing	190		645		655		550		440		2,480
Transmission and distribution	215		690		690		660		705		2,960
Nuclear fuel	70		125		205		245		245		890
General and other	45		190		120		80		85		520
Total	$	1,020	$	2,420	$	2,440	$	1,830	$	1,595	$	9,305
NEER:
Wind(d)	$	740	$	285	$	25	$	5	$	5	$	1,060
Solar(e)	390		670		160		5		—		1,225
Nuclear(f)	95		315		280		285		325		1,300
Other(g)	85		200		120		135		60		600
Total	$	1,310	$	1,470	$	585	$	430	$	390	$	4,185
Corporate and Other(h)	$	115	$	115	$	45	$	45	$	45	$	365

————————————

(a) Includes allowance for funds used during construction (AFUDC) of approximately $24 million, $82 million, $53 million, $48 million and $27 million in 2012 to 2016, respectively.

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

(c) Consists of projects that have received FPSC approval.  Includes pre-construction costs and carrying charges (equal to a pretax AFUDC rate) on construction costs recoverable through the capacity clause of approximately $24 million, $42 million and $12 million in 2012 to 2014, respectively.  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) Consists of capital expenditures for planned new wind projects and related transmission totaling approximately 1,500 mw, including approximately 150 mw in Canada, that have received applicable internal approvals.  Excludes new Canadian wind projects requiring internal approvals with generation totaling approximately 470 mw in 2014 and 2015, with an estimated cost of approximately $1.3 billion to $1.5 billion.

(e) Consists of capital expenditures for planned new solar projects and related transmission totaling 625 mw that have received applicable internal approvals, including equity contributions associated with a 50% equity method investment in a 550 mw solar project.  Excludes solar projects requiring internal approvals with generation totaling 270 mw with an estimated cost of approximately $600 million to $800 million.

(f) Includes nuclear fuel.

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

(h) Consists of capital expenditures that have received applicable internal approvals and includes AFUDC of approximately $9 million and $14 million in 2012 and 2013, respectively.

Required capacity and/or minimum payments under contracts

The required capacity and/or minimum payments under the contracts discussed above as of September 30, 2012 were estimated as follows:

	Remainder of 2012		2013		2014		2015		2016		Thereafter
	(millions)
FPL:
Capacity charges:(a)
Qualifying facilities	$	75	$	270	$	275	$	280	$	245	$	2,415
JEA and Southern subsidiaries	$	60	$	230	$	220	$	195	$	70	$	155
Minimum charges, at projected prices:
Natural gas, including transportation and storage(b)	$	495	$	1,580	$	1,065	$	570	$	535	$	6,935
Coal(b)	$	25	$	90	$	35	$	5	$	5	$	—
NEER	$	610	$	690	$	235	$	85	$	105	$	600
Corporate and Other(c)	$	65	$	30	$	10	$	15	$	15	$	20

————————————

(a) Capacity charges under these contracts, substantially all of which are recoverable through the capacity clause, totaled approximately $129 million and $128 million for the three months ended September 30, 2012 and 2011, respectively, and approximately $391 million and $383 million for the nine months ended September 30, 2012 and 2011, respectively. Energy charges under these contracts, which are recoverable through the fuel clause, totaled approximately $110 million and $135 million for the three months ended September 30, 2012 and 2011, respectively, and approximately $232 million and $348 million for the nine months ended September 30, 2012 and 2011, respectively.

(b) Recoverable through the fuel clause.

(c) Includes an approximately $68 million commitment to invest in clean power and technology businesses through 2017.

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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				9 Months Ended
	Sep. 30, 2012		Sep. 30, 2011		Sep. 30, 2012		Sep. 30, 2011
Realized and unrealized gains (losses): [Abstract]
Realized and unrealized gains (losses) reflected in operating revenues	$ (149)		$ (12)		$ 132		$ (11)
Unrealized gains (losses) reflected in operating revenues	(170)		12		41		37
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	575		155		486		296
Realized and unrealized gains (losses): [Abstract]
Included in Earnings	(149)	[1]	(11)	[1]	135	[2]	2	[2]
Included in regulatory assets and liabilities	1		0		7		2
Purchases	40		45		221		186
Settlements	30		3		(152)		(100)
Issuances	(21)		(70)		(221)		(260)
Transfers in	5	[3]	1	[3]	21	[4]	3	[4]
Transfers out	1	[3]	(2)	[3]	(15)	[4]	(8)	[4]
Fair value of net derivatives based on significant unobservable inputs, ending balance	482		121		482		121
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	(171)	[5]	12	[5]	41	[6]	42	[6]
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	7		5		4		7
Realized and unrealized gains (losses): [Abstract]
Included in Earnings	0		0		0		0
Included in regulatory assets and liabilities	1		0		7		2
Purchases	0		0		0		0
Settlements	(3)		(1)		(6)		(5)
Issuances	0		0		0		0
Transfers in	0		0		0		0
Transfers out	0		0		0		0
Fair value of net derivatives based on significant unobservable inputs, ending balance	5		4		5		4
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		$ 0		$ 0

[1] For the three months ended September 30, 2012 and 2011, $(149) million and $(12) million, respectively, of realized and unrealized gains (losses) are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

[2] For the nine months ended September 30, 2012 and 2011, $132 million and $(11) million, respectively, of realized and unrealized gains (losses) are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.

[3] For the three months ended September 30, 2012 and 2011, 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.

[4] For the nine months ended September 30, 2012 and 2011, 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.

[5] For the three months ended September 30, 2012 and 2011, $(170) million and $12 million, respectively, of unrealized gains (losses) are reflected in the condensed consolidated statements of income in operating revenues

[6] For the nine months ended September 30, 2012 and 2011, $41 million and $37 million, respectively, of unrealized gains (losses) 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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Fair Value Measurements (Policies)

9 Months Ended

Sep. 30, 2012

Fair Value Disclosures [Abstract]

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

Fair Value Measurements

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 and FPL primarily hold 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 significant other observable inputs.

NEE and FPL also enter 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.  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, through NEER, also enters into full requirements contracts, which, in many 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.  This consideration includes, but is not limited to, assumptions about market liquidity, volatility and contract duration as more fully described below in Significant Unobservable Inputs.

NEE uses interest rate and foreign currency swaps to mitigate and adjust interest rate and foreign currency exposure related to certain outstanding and forecasted debt issuances and borrowings.  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 swap agreements.