10-K

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2010

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 700 Universe Boulevard Juno Beach, Florida 33408 (561) 694-4000	59-0247775

State or other jurisdiction of incorporation or organization:Florida

		Name of exchange on which registered
Securities registered pursuant to Section 12(b) of the Act:
NextEra Energy, Inc.:	Common Stock, $0.01 Par Value	New York Stock Exchange
Florida Power & Light Company:   None

Indicate by check mark if the registrants are well-known seasoned issuers, as defined in Rule 405 of the Securities Act of 1933.

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

Indicate by check mark if the registrants are not required to file reports pursuant to Section 13 or Section 15(d) of the Securities Exchange Act of 1934.

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

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 ¨                                                                      Florida Power & Light Company    Yes þ    No ¨

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 ¨                                                                      Florida Power & Light Company    Yes ¨    No ¨

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrants' knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.  þ

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 the 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

Aggregate market value of the voting and non-voting common equity of NextEra Energy, Inc. held by non-affiliates as of June 30, 2010 (based on the closing market price on the Composite Tape on June 30, 2010) was $20,203,956,578.

There was no voting or non-voting common equity of Florida Power & Light Company held by non-affiliates as of June 30, 2010.

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 January 31, 2011: 420,952,376 shares.

As of January 31, 2011, 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.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of NextEra Energy, Inc.'s Proxy Statement for the 2011 Annual Meeting of Shareholders are incorporated by reference in Part III hereof.

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

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

DEFINITIONS

Acronyms and defined terms used in the text include the following:

Term	Meaning
AESO	Alberta Electric System Operator
AFUDC	allowance for funds used during construction
AFUDC - debt	debt component of allowance for funds used during construction
AFUDC - equity	equity component of allowance for funds used during construction
BART	Best Available Retrofit Technology
CAISO	California Independent System Operator
capacity clause	capacity cost recovery clause, as established by the FPSC
Capital Holdings	NextEra Energy Capital Holdings, Inc., formerly known as FPL Group Capital Inc
charter	restated articles of incorporation, as amended, of NextEra Energy or FPL, as the case may be
conservation clause	energy conservation cost recovery clause, as established by the FPSC
Dodd-Frank Act	Dodd-Frank Wall Street Reform and Consumer Protection Act
DOE	U.S. Department of Energy
Duane Arnold	Duane Arnold Energy Center
environmental clause	environmental compliance cost recovery clause, as established by the FPSC
EPA	U.S. Environmental Protection Agency
ERCOT	Electric Reliability Council of Texas
FDEP	Florida Department of Environmental Protection
FERC	Federal Energy Regulatory Commission
FPL	Florida Power & Light Company
FPL FiberNet	FPL FiberNet, LLC
FPSC	Florida Public Service Commission
fuel clause	fuel and purchased power cost recovery clause, as established by the FPSC
GHG	greenhouse gas(es)
IESO	Independent Electricity System Operator
ISONE	ISO New England
ITCs	investment tax credits
kv	kilovolt(s)
kw	kilowatt
kwh	kilowatt-hour(s)
Lone Star	Lone Star Transmission, LLC
Management's Discussion	Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations
MISO	Midwest Independent Transmission System Operator, Inc.
mortgage	mortgage and deed of trust dated as of January 1, 1944, from FPL to Deutsche Bank Trust Company Americas, as supplemented and amended
mw	megawatt(s)
NEPOOL	New England Power Pool
NERC	North American Electric Reliability Corporation
NextEra Energy	NextEra Energy, Inc., formerly known as FPL Group, Inc.
NextEra Energy Resources	NextEra Energy Resources, LLC
Note ___	note ___ to consolidated financial statements
NRC	U.S. Nuclear Regulatory Commission
NYISO	New York Independent System Operator
O&M expenses	other operations and maintenance expenses in the consolidated statements of income
PJM	PJM Interconnection, L.L.C.
PMI	NextEra Energy Power Marketing, LLC
Point Beach	Point Beach Nuclear Power Plant
PTCs	production tax credits
PURPA	Public Utility Regulatory Policies Act of 1978, as amended
PV	photovoltaic
qualifying facilities	non-utility power production facilities meeting the requirements of a qualifying facility under the PURPA
Recovery Act	American Recovery and Reinvestment Act of 2009, as amended
regulatory ROE	return on common equity as determined for regulatory purposes
ROE	return on common equity
RPS	renewable portfolio standards
Seabrook	Seabrook Station
SEC	U.S. Securities and Exchange Commission
SEGS	Solar Electric Generating System
SPP	Southwest Power Pool
WCEC	FPL's West County Energy Center in western Palm Beach County, Florida

NextEra Energy, FPL, Capital Holdings and NextEra Energy Resources 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 NextEra Energy, FPL, Capital Holdings and NextEra Energy Resources 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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TABLE OF CONTENTS

		Page No.
Definitions		2
Forward-Looking Statements		3
	PART I
Item 1.	Business	4
Item 1A.	Risk Factors	19
Item 1B.	Unresolved Staff Comments	28
Item 2.	Properties	29
Item 3.	Legal Proceedings	32
	PART II
Item 5.	Market for Registrants' Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	32
Item 6.	Selected Financial Data	33
Item 7.	Management's Discussion and Analysis of Financial Condition and Results of Operations	34
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	57
Item 8.	Financial Statements and Supplementary Data	58
Item 9.	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	111
Item 9A.	Controls and Procedures	111
Item 9B.	Other Information	111
	PART III
Item 10.	Directors, Executive Officers and Corporate Governance	112
Item 11.	Executive Compensation	112
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	112
Item 13.	Certain Relationships and Related Transactions, and Director Independence	112
Item 14.	Principal Accounting Fees and Services	112
	PART IV
Item 15.	Exhibits, Financial Statement Schedules	113
Signatures		121

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, 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 accom panied by, important factors included in Part I, Item 1A. Risk 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's and/or FPL's operations and financial results, and could cause NextEra Energy'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 NextEra Energy and/or FPL in this combined Form 10-K, in presentations, on their respective websites, in response to questions or otherwise.

Any forward-looking statement speaks only as of the date on which such statement is made, and NextEra Energy 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.

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PART I

Item 1.  Business

NEXTERA ENERGY

NextEra Energy is one of the largest electric power companies in North America and the U.S. leading producer of renewable energy from wind and solar projects.  At December 31, 2010, NextEra Energy had nearly 43,000 mw of generating capacity - approximately 53% natural gas, 19% wind, 13% nuclear, 13% oil and coal, and 2% hydro and solar.  NextEra Energy’s clean generation fleet gives the company significantly lower emissions rates of carbon dioxide, sulfur dioxide and nitrogen oxide than the electric power industry as a whole.  In addition to fuel diversity, NextEra Energy has geographic diversity with approximately 15,000 employees overseeing operations in 28 states and Canada.  Wind assets are in service in 17 states and three Canadian provinces.  NextEra Energy also operat es the third-largest nuclear fleet in the United States with eight units at five plants in four states.

NextEra Energy was incorporated in 1984 under the laws of Florida and has two principal operating subsidiaries, FPL and NextEra Energy Resources.  FPL is a rate-regulated utility engaged primarily in the generation, transmission, distribution and sale of electric energy in Florida.  NextEra Energy Resources is NextEra Energy's competitive energy subsidiary which produces the majority of its electricity from clean and renewable fuels.  Capital Holdings, a wholly-owned subsidiary of NextEra Energy, holds the capital stock of, or has equity interests in, and provides funding for, NextEra Energy's operating subsidiaries, other than FPL and its subsidiaries, including NextEra Energy Resources.  For a discussion of FPL's and NextEra Energy Resources' businesses, see FPL Operations and NextEra Energy R esources Operations below.  For financial information regarding NextEra Energy's business segments, see Note 15.

Website Access to SEC Filings.  NextEra Energy 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 NextEra Energy's internet website, www.nexteraenergy.com, as soon as reasonably practicable after they are electronically filed with or furnished to the SEC.  Information on NextEra Energy's website (or any of its subsidiaries' websites) is not incorporated by reference in this combined annual report on Form 10-K.  The SEC maintains an internet website at www.sec.gov that contains reports, proxy statements and other information about NextEra Energy and FPL filed electronically with the SEC.< /font>

FPL OPERATIONS

General.  FPL is the largest electric utility in the state of Florida, serving more than 8.7 million people through approximately 4.5 million customer accounts, and one of the largest electric utilities in the United States.  FPL supplies electric service throughout most of the east and lower west coasts of Florida.  Incorporated under the laws of Florida in 1925, FPL is a wholly-owned subsidiary of NextEra Energy.

FPL is a vertically integrated, rate-regulated utility with 23,722 mw of generating assets as of December 31, 2010.  FPL’s typical monthly residential customer bill was the lowest of all 55 electricity providers in the state of Florida as of December 31, 2010, and was 24% below the national average as of July 2010, the most recent data available.

During 2010, FPL delivered 99.98% service reliability to its customers, and was in the top quartile nationwide for reliability based on 2009, the most recent data available.  With a generating fleet that produces 78% of its electric power from natural gas and nuclear, FPL is also one the cleanest utilities in the nation, with an overall carbon dioxide emissions rate 35% below the industry average.

During 2010, FPL completed construction of a 75 mw hybrid solar power facility that combines a solar-thermal trough array with an existing combined-cycle natural gas plant.  FPL has 110 mw of solar generating capacity in its portfolio, more than any other utility outside of California.

FPL’s fossil fleet achieved a record level of fuel efficiency in 2010, with a system-wide heat rate of 8,043 British thermal units per kwh compared with 10,060 for the industry as a whole in 2009, the most recent data available.  FPL has maintained operational efficiency as well, with O&M expenses for 2010 of 1.5 cents per kwh, compared with a 2009 industry average of 2.2 cents per kwh.

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The percentage of FPL's operating revenues by customer class was as follows:

	Years Ended December 31,
	2010			2009			2008
Residential		54	%		56	%		53	%
Commercial		37			41			40
Industrial		2			3			3
Wholesale		1			1			1
Other, including deferred or recovered retail clause revenues, the net change in retail unbilled revenues, pole attachment rentals, transmission sales and customer-related fees		6			(1	)		3
		100	%		100	%		100	%

Regulation.  FPL's retail operations provided approximately 98% of FPL's 2010 operating revenues.  Retail operations are regulated by the FPSC, which has jurisdiction over retail rates, service territory, issuances of securities, planning, siting and construction of facilities and other matters.  FPL is also subject to regulation by the FERC with respect to certain aspects of its operations, including, but not limited to, the acquisition and disposition of facilities, interchange and transmission services and wholesale purchases and sales of electric energy.  FPL must also comply with mandatory reliability standards established by the NERC to ensure the reliability of the U.S. electric transmission and generation system and to prevent major system blackouts.  In addition, FPL's nuclear power plants are subject to the jurisdiction of the NRC.  NRC regulations govern the granting of licenses for the construction, operation and maintenance and retirement of nuclear power plants and subject these plants to continuing review and regulation.

Retail Ratemaking.  The underlying concept of utility ratemaking is to set rates at a level that allows the utility the opportunity to collect from customers total revenues (revenue requirements) equal to its cost of providing service, including a reasonable rate of return on invested capital.  To accomplish this, the FPSC uses various ratemaking mechanisms, including, among other things, base rates and cost recovery clauses.

Base Rates - In general, the basic costs of providing electric service, other than fuel and certain other costs, are recovered through base rates, which are designed to recover the costs of constructing, operating and maintaining the utility system.  These basic costs include O&M expenses, depreciation and taxes, as well as a return on FPL's investment in assets used and useful in providing electric service (rate base).  At the time base rates are determined, the allowed rate of return on rate base approximates the FPSC's determination of FPL's estimated weighted-average cost of capital, which includes its costs for outstanding debt and an allowed ROE.  The FPSC monitors FPL's actual regulatory ROE through a surveillance report that is filed mon thly by FPL with the FPSC.  The FPSC does not provide assurance that an allowed ROE will be achieved.  Base rates are determined in rate proceedings or through negotiated settlements, which occur at the initiative of FPL, the FPSC, the State of Florida Office of Public Counsel or a substantially affected party.  Base rates remain in effect until new base rates are approved by the FPSC.

Effective March 1, 2010, pursuant to an FPSC final order (FPSC rate order) with regard to FPL’s March 2009 petition (2009 rate case) that requested, among other things, a permanent base rate increase, new retail base rates for FPL were established, resulting in an increase in retail base revenues of approximately $75 million on an annualized basis.  The FPSC rate order also established a regulatory ROE of 10.0% with a range of plus or minus 100 basis points and an adjusted regulatory equity ratio of 59.1%, and shifted certain costs from retail base rates to the capacity clause.  In addition, the FPSC rate order directed FPL to reduce depreciation expense (surplus depreciation credit) over the 2010 to 2013 period related to a depreciation reserve surplus.  In August 2010, FPL, the State of Flori da Office of Public Counsel, the Florida Attorney General's Office and all other principal parties in FPL's 2009 rate case signed a stipulation and settlement regarding FPL's base rates (2010 rate agreement).  In December 2010, the FPSC voted to approve the 2010 rate agreement and on February 1, 2011 issued a final order reflecting its decision to approve the 2010 rate agreement.  Key elements of the 2010 rate agreement, which will be effective through December 31, 2012, are as follows:

· Subject to the provisions of the 2010 rate agreement, retail base rates will be effectively frozen through the end of 2012.

· Incremental cost recovery through FPL’s capacity clause for the new combined-cycle natural gas unit at WCEC (WCEC Unit No. 3), which is expected to be placed in service by mid-2011, will be permitted up to the amount of the projected fuel savings for customers during the term of the 2010 rate agreement.  See Fossil Operations below.

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

· If FPL's earned regulatory ROE falls below 9%, FPL may seek retail base rate relief.  If FPL's earned regulatory ROE rises above 11%, any party to the 2010 rate agreement may seek a reduction in FPL’s retail base rates.  In determining the regulatory ROE for all purposes under the 2010 rate agreement, earnings will be calculated on an actual, non-weather-adjusted basis.

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· FPL can vary the amount of surplus depreciation credit taken in any calendar year up to a cap in 2010 of $267 million, a cap in subsequent years of $267 million plus the amount of any unused portion from prior years, and a cap of $776 million (surplus depreciation credit cap) over the course of the 2010 rate agreement, provided that in any year of the 2010 rate agreement, including 2010, FPL must use at least enough surplus depreciation credit to maintain a 9% earned regulatory ROE but may not use any amount of surplus depreciation credit that would result in an earned regulatory ROE in excess of 11%.

Prior to the date new retail base rates were effective pursuant to the FPSC rate order, FPL's retail base rates were determined in accordance with the terms of a rate agreement approved in 2005 (2005 rate agreement), which was effective January 1, 2006.  See Management's Discussion - Overview for a discussion of the 2005 rate agreement.

Cost Recovery Clauses - Cost recovery clauses, which are designed to permit full recovery of certain costs and provide a return on certain assets allowed to be recovered through the various clauses, include substantially all fuel, purchased power and interchange expenses, conservation and certain environmental-related expenses, certain revenue taxes and franchise fees.  Beginning in 2009, pre-construction costs and carrying charges for FPL's two additional nuclear units at Turkey Point and carrying charges on construction costs for FPL's approximately 400 mw to 460 mw of additional capacity at St. Lucie and Turkey Point are also recovered through a cost recovery clause.  Also beginning in 2009, costs incurred for FPL's three solar generating facilities are re covered through a cost recovery clause.  Cost recovery clause costs are recovered through levelized monthly charges per kwh or kw, depending on the customer's rate class.  These cost recovery clause charges are calculated at least annually based on estimated costs and estimated customer usage for the following year, plus or minus a true-up adjustment to reflect the variance of actual costs and usage from the estimates used in setting the adjustment charges for prior periods.  An adjustment to the levelized charges may be approved during the course of a year to reflect revised estimates.

In 2010, fuel clause recoveries were approximately $4.5 billion.  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.  See Energy Marketing and Trading below, Management's Discussion - Results of Operations - FPL, Note 1 - Regulation and Note 3.

Capacity payments to other utilities and generating companies for purchased power are recovered from customers through the capacity clause.  Prior to March 2010, such payments were recovered through the capacity clause and base rates.  In accordance with the FPSC's nuclear cost recovery rule, FPL also recovers pre-construction costs and carrying charges (equal to a pretax AFUDC rate) on construction costs for new nuclear capacity through the capacity clause.  As property related to the new capacity goes into service, construction costs are recovered through base rate increases.  See Nuclear Operations below.  In accordance with the 2010 rate agreement, cost recovery for WCEC Unit No. 3, which is expected to be placed in service by mid-2011, will be permitted up to the amount of the pro jected fuel savings for customers during the term of the 2010 rate agreement through FPL's capacity clause and will be reported as retail base revenues.  See Base Rates above.  In 2010, capacity clause recoveries were approximately $606 million.

Costs associated with implementing energy conservation programs are recovered from customers through the conservation clause.  In 2010, conservation clause recoveries were approximately $187 million.  Certain costs of complying with federal, state and local environmental regulations enacted after April 1993 and costs associated with FPL's three solar facilities are recovered through the environmental clause.  In 2010, environmental clause recoveries were approximately $175 million.  See Environmental and Solar Operations below.

The FPSC has the authority to disallow recovery of costs that it considers excessive or imprudently incurred.  Such costs may include, among others, fuel and O&M expenses, the cost of replacing power lost when fossil and nuclear units are unavailable, storm restoration costs and costs associated with the construction or acquisition of new facilities.

Competition.  FPL currently holds 176 franchise agreements to provide electric service in various municipalities and counties in Florida with varying expiration dates through 2040.  Of the 176 franchise agreements, 8 expire in 2011, 7 expire in 2012 and 161 expire during the period 2013 through 2040.  Negotiations are ongoing to renew franchises with upcoming expirations.  FPL also provides service to 13 other municipalities and to 22 unincorporated areas within its service area without franchise agreements.  FPL considers its franchises to be adequate for the conduct of its business.

FPL currently faces competition from other suppliers of electrical energy to wholesale customers and from alternative energy sources and self-generation for other customer groups, primarily industrial customers.  The FERC has jurisdiction over potential changes that could affect competition in wholesale transactions.  In 2010, operating revenues from wholesale and industrial customers combined represented approximately 3% of FPL's total operating revenues.  Various states, other than Florida, have enacted legislation or have state commissions that have issued orders designed to allow retail customers to choose their electricity supplier.  Management believes it is unlikely there will be any state actions to restructure the retail electric industry in Florida in the near future.  If the basis of regulation for some or all of FPL's business changes from cost-based regulation, existing regulatory assets and liabilities would be written off unless regulators specify an alternative means of recovery or refund.  Further, other aspects of the business, such as generation assets and long-term power purchase commitments, would need to be reviewed to assess their recoverability in a changed regulatory environment.  See Management's Discussion - Critical Accounting Policies and Estimates - Regulatory Accounting.

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The FPSC promotes cost competitiveness in the building of new steam generating capacity by requiring investor-owned electric utilities, such as FPL, to issue a request for proposal (RFP) except when the FPSC determines that an exception from the RFP process is in the public interest.  The RFP process allows independent power producers and others to bid to supply the new generating capacity.  If a bidder has the most cost-effective alternative, meets other criteria such as financial viability and demonstrates adequate expertise and experience in building and/or operating generating capacity of the type proposed, the investor-owned electric utility would seek to negotiate a power purchase agreement with the selected bidder and request that the FPSC approve the terms of the power purchase agreement and, if appropriate , provide the required authorization for the construction of the bidder's generating capacity.  New nuclear power plants are exempt from the RFP requirement.  See Nuclear Operations below regarding the approval by the FPSC for two additional nuclear units at Turkey Point.

Environmental.  FPL is subject to environmental laws and regulations and is affected by some of the emerging issues included in the Environmental Matters section.  FPL expects to seek recovery through the environmental clause for compliance costs associated with any new environmental laws and regulations.

During 2010, FPL spent approximately $181 million on capital additions related to environmental matters, primarily to comply with existing environmental laws and regulations.  FPL's capital expenditures related to environmental matters are estimated to be $228 million for 2011 through 2013, including approximately $122 million in 2011, and are included in estimated planned capital expenditures set forth in Capital Expenditures below.

System Capability and Load.  At December 31, 2010, FPL's resources for serving load consisted of 25,800 mw, of which 23,722 mw were from FPL-owned facilities (see Item 2 - Generating Facilities) and 2,078 mw were available through purchased power contracts (see Note 14 - Contracts).  FPL's projected reserve margin for the summer of 2011 is approximately 23%.  This reserve margin is expected to be achieved through the combination of output from FPL's active generating units (excluding solar, which is not considered a firm energy generator resource), purchased power contracts and the capability to reduce peak demand through the implementation of demand side management (DSM) programs, including load management, which was estimated at December 31, 2010 to be capable of reducing demand by 1,805 mw, and energy efficiency and conservation programs.  In 2009, the FPSC issued an order that will require Florida utilities, including FPL, to meet higher DSM goals for both demand and energy.  FPL submitted its DSM plan to the FPSC in 2010 and, in January 2011, the FPSC ordered FPL to submit a revised plan by March 2011.  Once a DSM plan is approved by the FPSC, program standards will be submitted to the FPSC for approval.  Occasionally, unusually cold temperatures during the winter months result in significant increases in electricity usage for short periods of time.  However, customer usage and operating revenues are typically higher during the summer months, largely due to the prevalent use of air conditioning in FPL's service territory.  The highest peak load FPL has served to date was 24,346 mw, which occurred on January 11, 2010.  FPL had adequate res ources available at the time of this peak to meet customer demand.  See Fossil Operations and Nuclear Operations below regarding generation projects currently under construction.

Fuel Mix.  FPL's generating plants use a variety of fuels.  The diverse fuel sources, along with purchased power, are intended to enable FPL to shift between sources of generation to achieve a more economical fuel mix.  See Fossil Operations and Nuclear Operations below, and Item 2 - Generating Facilities.

FPL's 2010 fuel mix based on kwh produced was as follows:

Fuel Source	Percentage of kwh Produced
Natural gas	58	%
Nuclear	20	%
Purchased power	13	%
Coal	5	%
Oil	4	%
Solar	<1	%

Fossil Operations.  At December 31, 2010, FPL owned and operated 79 units that used fossil fuels such as natural gas and/or oil, and has a joint-ownership interest in three coal units.  These fossil units are out of service from time to time for routine maintenance or on standby during periods of reduced electricity demand.  FPL is currently constructing WCEC Unit No. 3, a natural gas-fired combined-cycle unit of approximately 1,220 mw, which is expected to be placed in service by mid-2011.  FPL is also in the process of modernizing its Cape Canaveral and Riviera Beach power plants to high-efficiency natural gas-fired units and expects the units to be placed in service by 2013 and 2014, respectively.  Each mo dernized plant is expected to provide approximately 1,200 mw of capacity.  See Capital Expenditures below.

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FPL has several firm transportation contracts in place with four different suppliers with expiration dates ranging from 2013 to 2036 that together are expected to satisfy substantially all of the anticipated needs for natural gas transportation at its existing units.  To the extent desirable, FPL purchases interruptible natural gas transportation service from two suppliers based on pipeline availability.  FPL has several short- and medium-term natural gas supply contracts to provide a portion of FPL's anticipated needs for natural gas.  The remainder of FPL's natural gas requirements is purchased in the spot market.  FPL has a long-term agreement for the storage of natural gas that expires in 2013.  See Note 14 - Contracts.  FPL's oil requirements are obtained under shor t-term contracts and in the spot market.

FPL has, through its joint ownership interest in St. Johns River Power Park (SJRPP) Units Nos. 1 and 2, a coal supply and transportation contract for all of the 2011 fuel needs and a portion of the 2012 and 2013 fuel needs for those units.  All of the transportation requirements and a portion of the coal supply needs for Scherer Unit No. 4 are covered by a series of annual and long-term contracts.  FPL's remaining fuel requirements for these units will be obtained in the spot market.  See Note 14 - Contracts.

Nuclear Operations.  FPL owns, or has undivided interests in, and operates four nuclear units, two at Turkey Point and two at St. Lucie, with a total net generating capability of 2,939 mw.  The nuclear units are periodically removed from service to accommodate normal refueling and maintenance outages, including inspections, repairs and certain other modifications.  Scheduled nuclear refueling outages typically require the unit to be removed from service for approximately 30 days.  This duration is longer for expanded scope outages, three of which are scheduled in 2011 related to the addition of capacity at FPL's existing nuclear units.  The following table summarizes certain information related to FPL's nuclear un its:

Facility	Net Capability (mw)	Operating License Expiration Dates	Next Scheduled Refueling Outage
St. Lucie Unit No. 1	839	2036	August 2011
St. Lucie Unit No. 2	714	2043	April 2012
Turkey Point Unit No. 3	693	2032	January 2012
Turkey Point Unit No. 4	693	2033	March 2011

FPL is in the process of adding approximately 400 mw to 460 mw of capacity at its existing nuclear units at St. Lucie and Turkey Point, which additional capacity is projected to be placed in service from spring 2011 to 2013.  The construction costs relating to the increase in capacity yet to be incurred as of December 31, 2010 are included in the estimated planned capital expenditures set forth in Capital Expenditures below.  As part of the conditions of certification by the FDEP for the Turkey Point project, FPL was required to implement a monitoring plan in and around the Turkey Point cooling canals due to concerns over potential saltwater intrusion beyond FPL's property.  Monitoring under the plan includes collection of data for a minimum of two years prior to and two years after the date the addi tional capacity is placed in service. The monitoring plan is designed to establish a baseline and assess the vertical and horizontal effects of the cooling canal system on existing and projected surface and groundwater and ecological conditions surrounding Turkey Point. The ultimate results of the monitoring plan are uncertain, and the financial and operational impacts on FPL, if any, cannot be determined at this time.  In 2008, the FPSC approved FPL's need petition for two additional nuclear units at its Turkey Point site.  The two units combined are expected to add approximately 2,200 mw of capacity and have projected in-service dates between 2022 and 2023.  Additional approvals from other regulatory agencies will be required later in the development process.  See Capital Expenditures below.

FPL has several contracts for the supply of uranium, conversion, enrichment and fabrication of nuclear fuel with expiration dates ranging from March 2011 through 2022.  See Note 14 - Contracts.  Under the Nuclear Waste Policy Act of 1982, as amended (Nuclear Waste Policy Act), the DOE is responsible for the development of a repository for the disposal of spent nuclear fuel and high-level radioactive waste.  As required by the Nuclear Waste Policy Act, FPL is a party to contracts with the DOE to provide for disposal of spent nuclear fuel from its Turkey Point and St. Lucie nuclear units.  The DOE was required to construct permanent disposal facilities and take title to and provide transportation and disposal for spent nuclear fuel by January 31, 1998 for a specified fee based on current gene ration from nuclear power plants.  Through December 31, 2010, FPL has paid approximately $651 million in such fees to the U.S. Government's nuclear waste fund.  The DOE did not meet its statutory obligation for disposal of spent nuclear fuel under the Nuclear Waste Policy Act.  In 2009, FPL and certain nuclear plant joint owners signed a settlement agreement (spent fuel settlement agreement) with the U.S. Government agreeing to dismiss with prejudice lawsuits filed against the U.S. Government seeking damages caused by the DOE's failure to dispose of spent nuclear fuel from FPL's nuclear plants.  The spent fuel settlement agreement permits FPL to make annual filings to recover certain spent fuel storage costs incurred by FPL which will be payable by the U.S. Government on an annual basis.  Through December 31, 2010, FPL has collected approximately $121 million from the U.S. Government pursuant to the spent fuel settlement agreement and has paid appro ximately $6 million to the joint owners of St. Lucie Unit No. 2.  FPL will continue to pay fees to the U.S. Government's nuclear waste fund.  In March 2010, the DOE filed a motion with the NRC to withdraw its license application for a high-level nuclear waste repository at Yucca Mountain.  The DOE’s withdrawal motion has been challenged and is being litigated before the NRC and the U.S. Court of Appeals for the District of Columbia (D.C. Circuit).  In light of the Obama Administration's decision not to proceed with the Yucca Mountain repository project, the DOE has established a Blue Ribbon Commission on America's Nuclear Future (BRC) to conduct a comprehensive review of policies for managing the back end of the nuclear fuel cycle and to provide recommendations for developing a safe, long-term solution to managing used nuclear fuel and nuclear waste.  The BRC is scheduled to complete its activities in January 2012.

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FPL uses both on-site storage pools and dry storage casks to store spent nuclear fuel generated by St. Lucie Units Nos. 1 and 2, which should allow FPL to store all spent nuclear fuel at this facility through license expiration.  FPL currently stores all spent nuclear fuel generated by Turkey Point Units Nos. 3 and 4 in on-site storage pools.  These spent nuclear fuel storage pools do not have sufficient storage capacity for the life of the respective units.  In July 2011, FPL plans to begin using dry storage casks to store spent nuclear fuel generated by the Turkey Point facility, which should allow FPL to store spent nuclear fuel at this facility through license expiration.

The NRC's regulations require FPL to submit a plan for decontamination and decommissioning five years before the projected end of plant operation.  FPL's current plans, under the operating licenses, provide for prompt dismantlement of Turkey Point Units Nos. 3 and 4 with decommissioning activities commencing in 2032 and 2033, respectively.  Current plans provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the prompt dismantlement of St. Lucie Unit No. 2 at the end of its useful life in 2043.  See estimated decommissioning cost data in Management's Discussion - Critical Accounting Policies and Estimates - Nuclear Decommissioning and Fossil/Solar Dismantlement.

Solar Operations.FPL placed its first utility-scale solar generating facility into service in 2009 and placed two additional solar generating facilities in service in 2010.  FPL's three solar generating facilities consist of a 25 mw solar PV facility in DeSoto County, Florida, a 10 mw solar PV facility in Brevard County, Florida and a 75 mw solar thermal facility in Martin County, Florida.

Energy Marketing and Trading.  FPL's Energy Marketing & Trading division (EMT) buys and sells wholesale energy commodities, such as natural gas, oil and electricity.  EMT procures natural gas and oil for FPL's use in power generation and sells excess natural gas, oil and electricity.  EMT also uses derivative instruments, such as swaps, options and forwards, to manage the commodity price risk inherent in the purchase and sale of fuel and electricity.  Substantially all of the results of EMT's activities are passed through to customers in the fuel or capacity clauses.  See Retail Ratemaking above, Management's Discussion - Results of Operations - FPL and Energy Marketing and Trading and Market Risk Sensitivity and Note 3.

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.

FPL's actual capital expenditures for 2008 through 2010 and estimated planned capital expenditures for 2011 through 2015 as of December 31, 2010 were as follows:

	Actual						Planned
	2008		2009		2010		2011		2012		2013		2014		2015		Total
(millions)
Generation:(a)
New(b)(c)	$	880	$	1,203	$	1,148	$	1,520	$	1,870	$	500	$	105	$	-	$	3,995
Existing		601		651		588		655		570		610		665		490		2,990
Transmission and distribution		744		633		606		720		870		820		760		840		4,010
Nuclear fuel		130		178		98		260		170		255		205		220		1,110
General and other		94		102		101		120		145		95		120		105		585
Total	$	2,449	$	2,767	$	2,541	$	3,275	$	3,625	$	2,280	$	1,855	$	1,655	$	12,690

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(a)	Includes AFUDC of approximately $49 million, $76 million, $79 million, $29 million and $3 million in 2011 to 2015, respectively.
(b)	Includes land, generating structures, transmission interconnection and integration and licensing.
(c)	Includes 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 $98 million, $75 million and $24 million in 2011 to 2013, 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.

These estimates are subject to continuing review and adjustment and actual capital expenditures may vary significantly from these estimates.  See Management's Discussion - Liquidity and Capital Resources - Contractual Obligations and Estimated Planned Capital Expenditures and Note 14 - Commitments.

Electric and Magnetic Fields.  Electric and magnetic fields (EMF) are present around electrical facilities, including, but not limited to, appliances, power lines and building wiring.  Since the 1970s, there has been public, scientific and regulatory attention given to the question of whether EMF causes or contributes to adverse health effects.  U.S. and international scientific organizations have evaluated the EMF research.  Their reviews have generally concluded that while some epidemiology studies report an association with childhood leukemia, controlled laboratory studies do not support that association and the scientific studies overall have not demonstrated that EMF cause or contribute to any type of cancer or other d isease.

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The FDEP established EMF standards for electricity facilities in 1989 and FPL facilities comply with these standards.  Future changes in the FDEP regulations could require additional capital expenditures by FPL for such things as increasing the width of right of ways or relocating or reconfiguring transmission facilities.  It is not presently known whether any such expenditures will be required.  Currently, there are no such changes proposed to the FDEP regulations.

Employees.  FPL had approximately 10,000 employees at December 31, 2010.  Approximately 32% of the employees are represented by the International Brotherhood of Electrical Workers (IBEW) under a collective bargaining agreement with FPL that expires October 31, 2011.

NEXTERA ENERGY RESOURCES OPERATIONS

General.  NextEra Energy Resources is one of the largest wholesale generators of electric power in the United States, with 18,866 mw of generating assets across 26 states as of December 31, 2010.  The company also owns and operates wind projects in the Canadian provinces of Nova Scotia, Quebec and Alberta.  NextEra Energy Resources is the largest owner of wind and solar energy projects in the United States and the fourth largest owner of wind projects in Canada.

Of NextEra Energy Resources’ net generating capability at December 31, 2010, more than 11,300 mw were contracted and approximately 5,800 mw operate on a merchant basis.  Its wind portfolio has expanded from 1,745 mw in 2002 to 8,298 mw in 2010.  As of December 31, 2010, NextEra Energy Resources is the largest generator of solar energy in the United States, principally through a 310 mw facility in California’s Mojave Desert, of which 148 mw is owned by NextEra Energy Resources.  NextEra Energy Resources is pursuing additional commercial-scale solar projects in the United States, Canada and Spain.

A wholly-owned subsidiary of Capital Holdings, NextEra Energy Resources was formed in 1998 to aggregate NextEra Energy's existing competitive energy businesses.  It is a limited liability company organized under the laws of Delaware.  Through its subsidiaries, NextEra Energy Resources currently owns, develops, constructs, manages and operates electric-generating facilities in wholesale energy markets.  NextEra Energy Resources also provides full energy and capacity requirements services primarily to distribution utilities in certain markets and owns a retail electricity provider based in Texas.  NextEra Energy Resources also engages in power and gas marketing and trading activities.

At December 31, 2010, NextEra Energy Resources managed or participated in the management of essentially all of its projects in which it has an ownership interest.  NextEra Energy Resources had ownership interests in operating independent power projects with a net generating capability totaling 18,866 mw (see Item 2 - Generating Facilities).  Generation capacity spans various geographic regions in North America and is produced using a variety of fuel sources, thereby reducing overall volatility related to varying market conditions and seasonality on a portfolio basis.  At December 31, 2010, the percentage of capacity by geographic region was:

Geographic Region	Percentage of Generation Capacity
ERCOT	28	%
Northeast	27	%
Midwest	22	%
West	15	%
Other South	8	%

At December 31, 2010, fuel sources for these projects were as follows:

Fuel Source	Percentage of Generation Capacity
Wind	44	%
Natural Gas	35	%
Nuclear	14	%
Oil	4	%
Hydro	2	%
Solar and other	1	%

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NextEra Energy Resources' strategy is, among other things, to continue to maintain its leadership position in wind, accelerate growth in solar development, continue to expand its transmission capability, grow its customer supply and proprietary power and gas trading businesses, and develop its natural gas infrastructure business.  NextEra Energy Resources' customer supply business includes full energy and capacity requirements services and the operations of a retail electricity provider.  NextEra Energy Resources seeks to expand its generation portfolio primarily through wind and solar development and acquisitions where economic prospects are attractive.  NextEra Energy Resources plans to add approximately 3,500 mw to 5,000 mw of new wind generation in 2010 to 2014, including 754 mw added in 2010 and appr oximately 700 mw to 1,000 mw in 2011.  In addition to wind expansion, NextEra Energy Resources is considering several solar development opportunities in the United States and Europe, and plans to add approximately 400 mw to 600 mw of new solar generation in 2010 to 2014, including 5 mw added in 2010.  The wind and solar expansions are subject to, among other things, continued public policy support, support for the construction and availability of sufficient transmission facilities and capacity, continued market demand, supply chain expansion and access to capital at reasonable cost and on reasonable terms.  NextEra Energy Resources continues to invest in natural gas infrastructure opportunities.  NextEra Energy Resources is evaluating additional natural gas infrastructure opportunities and will continue to explore additional projects as opportunities that it believes will be economically attractive become available.

NextEra Energy Resources' actual capital expenditures and investments for 2008 through 2010 and estimated planned capital expenditures for 2011 through 2015 as of December 31, 2010 were as follows:

	Actual						Planned
	2008		2009		2010		2011		2012		2013		2014		2015		Total
	(millions)
Wind(a)	$	2,255	$	2,625	$	1,950	$	505	$	30	$	10	$	5	$	-	$	550
Solar(b)		20		40		185		955		885		420		75		-		2,335
Nuclear(c)		335		455		510		585		275		250		250		265		1,625
Natural gas		115		120		140		140		35		65		40		120		400
Other(d)		80		110		285		85		75		50		60		50		320
Total	$	2,805	$	3,350	$	3,070	$	2,270	$	1,300	$	795	$	430	$	435	$	5,230

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(a)	Consists of capital expenditures for planned new wind projects that have received applicable internal approvals and related transmission.  NextEra Energy Resources plans to add new wind generation of approximately 3,500 mw to 5,000 mw in 2010 to 2014, including 754 mw added in 2010 and approximately 700 mw to 1,000 mw in 2011, at a total cost of approximately $7 billion to $10 billion.
(b)	Consists of capital expenditures for planned new solar projects that have received applicable internal approvals and related transmission.  NextEra Energy Resources plans to add new solar generation of approximately 400 mw to 600 mw in 2010 through 2014, including 5 mw added in 2010, at a total cost of approximately $3 billion to $4 billion.
(c)	Includes nuclear fuel.
(d)	Consists of capital expenditures that have received applicable internal approvals.  NextEra Energy Resources plans to add natural gas infrastructure projects totaling approximately $400 million to $600 million in 2010 through 2014.

These estimates are subject to continuing review and adjustment and actual capital expenditures may vary significantly from these estimates.  See Management's Discussion - Liquidity and Capital Resources - Contractual Obligations and Estimated Planned Capital Expenditures and Note 14 - Commitments.

Portfolio by Category.NextEra Energy Resources' generating assets are categorized as follows:

Wind Assets - At December 31, 2010, NextEra Energy Resources had ownership interests in wind generating facilities with a combined capacity of approximately 8,298 mw (net ownership), of which approximately 79% have long-term contracts with utilities and power marketers, predominantly under fixed-price agreements with a weighted-average remaining contract life of 14 years.  The expected output of the remaining 21% is substantially hedged through 2012 and partially hedged through 2018 against changes in commodity prices.  NextEra Energy Resources operates substantially all of these wind facilities.  Approximately 91% of NextEra Energy Resources' net ownership in wind facilities has received exempt wholesale generator status as defined under the P ublic Utility Holding Company Act of 2005 (Holding Company Act).  Essentially all of the remaining facilities have qualifying facility status under PURPA.  NextEra Energy Resources' wind facilities are located in 17 states and Canada.  NextEra Energy Resources expects to add approximately 700 mw to 1,000 mw of new wind generation in 2011.

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Contracted Assets - At December 31, 2010, NextEra Energy Resources had 4,740 mw of non-wind contracted assets.  The contracted category includes all projects, other than wind, with contracts for substantially all of their output.  In 2010, two natural gas-fired plants, located in California and Pennsylvania, with a combined net generating capacity of approximately 1,250 mw moved from the merchant assets category to the contracted assets category when their respective long-term power sales agreements became effective.  Essentially all of the contracted assets were under power sales contracts with utilities, with a weighted-average remaining contract life of 14 years, and have firm fuel and transportation agreements with expiration dates ranging from December 2011 to 2033.  See Note 14 - Contracts.  Approximately 1,550 mw of this capacity is natural gas-fired generation.  The remaining 3,190 mw use a variety of fuels and technologies such as nuclear, oil, solar and coal.  As of December 31, 2010, approximately 95% of NextEra Energy Resources' contracted generating capacity is from power plants that have received exempt wholesale generator status under the Holding Company Act, while the remaining 5% has qualifying facility status under PURPA.  During the third quarter of 2011, a natural gas plant, located in the Northeast region, with a net generating capacity of approximately 145 mw will move to the merchant assets category when its long-term power sales agreement ends.

Merchant Assets - At December 31, 2010, NextEra Energy Resources' portfolio of merchant assets includes 5,828 mw of owned nuclear, natural gas, oil and hydro generation, of which 3,036 mw is located in the Northeast region and 2,792 mw in the ERCOT region.  The merchant assets include 1,017 mw of peak generating facilities.  Merchant assets are plants that do not have long-term power sales agreements to sell their output and therefore require active marketing and hedging.  Approximately 71% (based on net mw capability) of the natural gas fueled merchant assets have natural gas supply agreements or a combination of natural gas supply and transportation agreements to provide for on-peak natural gas requirements.   See Note 14 - Con tracts.  Derivative instruments (primarily swaps, options, futures and forwards) are used to lock in pricing and manage the commodity price risk inherent in power sales and fuel purchases.  Managing market risk through these instruments introduces other types of risk, primarily counterparty and operational risks.  See Energy Marketing and Trading below.

Nuclear Operations.  NextEra Energy Resources wholly owns, or has undivided interests in, four nuclear units with a total net generating capability of 2,554 mw.  NextEra Energy Resources is responsible for all nuclear unit operations and the ultimate decommissioning of the nuclear units, the cost of which is shared on a pro-rata basis by the joint owners for the jointly owned units.  See estimated decommissioning cost data in Management's Discussion - Critical Accounting Policies and Estimates - Nuclear Decommissioning and Fossil/Solar Dismantlement.  The nuclear units are periodically removed from service to accommodate normal refueling and maintenance outages, including inspections, repairs and certain other modifications .  The following table summarizes certain information related to NextEra Energy Resources' nuclear units:

Facility	Location	Net Capability (mw)		Portfolio Category	Operating License Expiration Dates			Next Scheduled Refueling Outage
Seabrook	New Hampshire		1,100	Merchant		2030	(a)	April 2011
Duane Arnold	Iowa		431	Contracted(b)		2034		October 2012
Point Beach Unit No. 1	Wisconsin		509	Contracted(c)		2030		October 2011
Point Beach Unit No. 2	Wisconsin		514	Contracted(c)		2033		March 2011

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(a)	In 2010, NextEra Energy Resources filed an application with the NRC to renew Seabrook's operating license for an additional 20 years.
(b)	NextEra Energy Resources sells substantially all of its share of the output of Duane Arnold under a long-term contract expiring in 2014.
(c)	NextEra Energy Resources sells 100% of the output of Point Beach Units Nos. 1 and 2 under a long-term contract through the current license terms.

NextEra Energy Resources is in the process of adding approximately 80 mw of capacity at each of its existing nuclear units at Point Beach during the scheduled refueling outages in the fall of 2011 for Unit No. 1 and the spring of 2011 for Unit No. 2.  The construction costs relating to the capacity additions yet to be incurred as of December 31, 2010 are included in estimated planned capital expenditures set forth in Capital Expenditures above.  See Note 14 - Commitments.

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NextEra Energy Resources' nuclear facilities have several contracts for the supply of uranium, conversion, enrichment and fabrication of nuclear fuel with expiration dates ranging from March 2011 through 2022.  See Note 14 - Contracts.  Under the Nuclear Waste Policy Act, the DOE is responsible for the development of a repository for the disposal of spent nuclear fuel and high-level radioactive waste.  As required by the Nuclear Waste Policy Act, subsidiaries of NextEra Energy Resources are parties to contracts with the DOE to provide for disposal of spent nuclear fuel from its Seabrook, Duane Arnold and Point Beach nuclear units.  The DOE was required to construct permanent disposal facilities and take title to and provide transportation and disposal for spent nuclear fuel by January  31, 1998 for a specified fee based on current generation from nuclear power plants.  The total cumulative amount of such fees paid to the U.S. Government's nuclear waste fund for Seabrook, Duane Arnold and Point Beach, including amounts paid by all joint owners, since the start of the plants' operations through December 31, 2010, is approximately $535 million, of which NextEra Energy Resources has paid approximately $115 million since the date of the plants' respective acquisitions.  The DOE did not meet its statutory obligation for disposal of spent nuclear fuel under the Nuclear Waste Policy Act.  In 2009, certain subsidiaries of NextEra Energy Resources and certain nuclear plant joint owners signed the spent fuel settlement agreement with the U.S. Government agreeing to dismiss with prejudice lawsuits filed against the U.S. Government seeking damages caused by the DOE's failure to dispose of spent nuclear fuel from the Seabrook, Duane Arnold and Point Beach nuclear plant s.  The spent fuel settlement agreement permits NextEra Energy Resources to make annual filings to recover certain spent fuel storage costs incurred by NextEra Energy Resources which will be payable by the U.S. Government on an annual basis.  Through December 31, 2010, NextEra Energy Resources has collected approximately $65 million from the U.S. Government pursuant to the spent fuel settlement agreement and has paid approximately $21 million to the joint owners of Duane Arnold and Seabrook.  NextEra Energy Resources will continue to pay fees to the U.S. Government's nuclear waste fund.  For discussion of current developments regarding a high-level nuclear waste repository see FPL - Nuclear Operations.  All of NextEra Energy Resources' nuclear facilities use both on-site storage pools and dry storage casks to store spent nuclear fuel generated by these facilities, which should allow NextEra Energy Resources to store spent nuclear fuel at these facilities through license expiration.

Energy Marketing and Trading.  PMI, a subsidiary of NextEra Energy Resources, buys and sells wholesale energy commodities, such as natural gas, oil and electricity.  Its primary role is to manage the commodity risk of NextEra Energy Resources' portfolio.  PMI sells the output from NextEra Energy Resources' plants that has not been sold under long-term contracts.  PMI procures natural gas and oil for NextEra Energy Resources' use in power generation, as well as substantially all of the electricity needs for NextEra Energy Resources' retail electricity provider operations, conducted primarily in Texas, which at December 31, 2010 served approximately 2,180 mw of peak load to approximately 189,000 customers.  PMI uses derivative instruments such as swaps, options, futures and forwards to manage the risk associated with fluctuating commodity prices and to optimize the value of NextEra Energy Resources' power generation assets.  PMI also provides full energy and capacity requirements services primarily to distribution utilities in certain markets and engages in power and gas marketing and trading activities to take advantage of expected future favorable price movements.  Full energy and capacity requirements services include load-following services, which require the supplier of energy to vary the quantity delivered based on the load demand needs of the customer, as well as various ancillary services.  At December 31, 2010, PMI provided full energy and capacity requirements services totaling approximately 5,820 mw of peak load in the NEPOOL, PJM, ERCOT, MISO and NYISO markets.  The results of PMI's activities are included in NextEra Energy Resources' operating results.  ; See Management's Discussion - Energy Marketing and Trading and Market Risk Sensitivity, Note 1 - Energy Trading and Note 3.

Regulation.  Each of the energy markets in which NextEra Energy Resources operates is subject to local, state and federal regulation, and other specific rules.  At December 31, 2010, NextEra Energy Resources had ownership interests in operating independent power projects that have received exempt wholesale generator status as defined under the Holding Company Act, which represent approximately 95% of NextEra Energy Resources' net generating capacity.  Exempt wholesale generators own or operate a facility exclusively to sell electricity to wholesale customers.  They are barred from selling electricity directly to retail customers.  NextEra Energy Resources' exempt wholesale generators produce electricity from wind, hydropower, fossil fuels and nuclear facilities.  Essentially all of the remaining 5% of NextEra Energy Resources' net generating capacity has qualifying facility status under PURPA.  NextEra Energy Resources' qualifying facilities generate electricity from wind, solar, fossil fuels and waste coal.  Qualifying facility status exempts the projects from, among other things, many of the provisions of the Federal Power Act, as well as state laws and regulations relating to rates and financial or organizational regulation of electric utilities.  While projects with qualifying facility and/or exempt wholesale generator status are exempt from various restrictions, each project must still comply with other federal, state and local laws, including, but not limited to, those regarding siting, construction, operation, licensing, pollution abatement and other environmental laws.

Additionally, regional transmission organizations (RTOs) and independent system operators (ISOs) exist in a number of regions to coordinate generation and transmission across wide geographic areas.  Although each RTO and ISO may have differing objectives and structures, some benefits of these entities include regional planning, managing transmission congestion, developing larger wholesale markets for energy and capacity, maintaining reliability, and facilitating competition among wholesale electricity providers.  NextEra Energy Resources currently has operations that fall within the following RTOs and ISOs: AESO, CAISO, ERCOT, IESO, ISONE, MISO, NYISO, PJM and SPP.  Additionally, certain NextEra Energy Resources facilities are subject to the NERC’s mandatory reliability standards, and its nucle ar facilities are also subject to the jurisdiction of the NRC.  See FPL - Regulation for further discussion of NERC and NRC regulations.

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NextEra Energy Resources continues to evaluate and participate in regional market redesigns of existing operating rules for the integration of renewable energy resources and for the purchase and sale of energy commodities.  In December 2010, ERCOT implemented a locational marginal price market design (a market-pricing approach used to manage the efficient use of the transmission system when congestion occurs on the electricity grid).  NextEra Energy Resources does not anticipate a material impact, if any, on its business resulting from implementation of the new market design.

Competition.  Competitive wholesale markets in the United States continue to evolve and vary among and within geographic regions.  Revenues from electricity sales in these markets vary based on the prices obtainable for energy, capacity and other ancillary services.  Some of the factors affecting success in these markets include the ability to operate generating assets efficiently and reliably, the price and supply of fuel, transmission constraints, wind, solar and hydro resources (weather conditions), competition from regulated utilities and new sources of generation, effective risk management, demand growth, level of demand, environmental requirements and exposure to legal and regulatory changes.

Expanded competition in a frequently changing regulatory environment presents both opportunities and risks for NextEra Energy Resources.  Opportunities exist for the selective acquisition of generation assets and for the construction and operation of efficient plants that can sell power in competitive markets.  NextEra Energy Resources seeks to reduce its market risk by having a diversified portfolio by fuel type and location, as well as by contracting for the future sale of a significant amount of the electricity output of its plants.

Environmental.  NextEra Energy Resources is subject to environmental laws and regulations and is affected by some of the emerging issues included in the Environmental Matters section.

During 2010, NextEra Energy Resources spent approximately $6 million on capital additions related to environmental matters, primarily to comply with existing environmental laws and regulations.  NextEra Energy Resources' capital expenditures related to environmental matters are estimated to be $5 million for 2011 through 2013, including approximately $3 million in 2011, and are included in estimated planned capital expenditures set forth in General above.

Employees.  NextEra Energy Resources and its subsidiaries had approximately 4,690 employees at December 31, 2010.  Subsidiaries of NextEra Energy Resources have collective bargaining agreements with various unions which are summarized in the table below.

Union	Location	Contract Expiration Date	% of NextEra Energy Resources Employees Covered
IBEW	Wisconsin	June 2012 - September 2013(a)		10	%
Utility Workers Union of America	New Hampshire	December 2013		5
IBEW	Iowa	May 2012		3
Security Police and Fire Professionals of America	Iowa	July 2012		3
IBEW	Maine	February 2013		2
IBEW	California	March 2012		-	(b)
Total				23	%

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(a)	Various employees at Point Beach are represented by the IBEW under four separate contracts with different expiration dates.
(b)	Employees constitute less than 1% of NextEra Energy Resources' employees.

OTHER NEXTERA ENERGY OPERATIONS

NextEra Energy's Corporate and Other segment represents other business activities, primarily FPL FiberNet and Lone Star, that are not separately reportable.  See Note 15.

FPL FiberNet.  FPL FiberNet, a wholly-owned subsidiary of Capital Holdings, was formed in 2000 to enhance the value of NextEra Energy's fiber-optic network assets that were originally built to support FPL operations.  Accordingly, in 2000, FPL's existing fiber-optic lines were transferred to FPL FiberNet.  FPL FiberNet is a limited liability company organized under the laws of Delaware.  FPL FiberNet leases wholesale fiber-optic network capacity and dark fiber to FPL and other customers, primarily telephone, wireless carriers, internet and other telecommunications companies.  FPL FiberNet's primary business focus is the Florida metropolitan (metro) market.  Metro networks cover Miami, Fort Lauderdale, We st Palm Beach, Tampa, St. Petersburg, Orlando, Jacksonville, Naples, Ft. Myers and Tallahassee.  FPL FiberNet also has a long-haul network within Florida that provides bandwidth at wholesale rates.  At December 31, 2010, FPL FiberNet's network consisted of approximately 4,030 route miles, which interconnect major cities throughout Florida.

At December 31, 2010, NextEra Energy's investment in FPL FiberNet totaled approximately $180 million.  FPL FiberNet invested approximately $48 million during 2010 and plans to invest a total of approximately $180 million over the next five years primarily to meet customers' specific requirements under contract.

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Lone Star.In 2008, the Public Utility Commission of Texas (PUCT) approved a $4.9 billion transmission grid improvement program that would add approximately 2,300 miles of 345 kv lines to deliver power from the Competitive Renewable Energy Zones (CREZ) in west Texas and the Texas panhandle to the Dallas/Fort Worth area and other population centers in Texas.  In 2009, Lone Star, an indirect wholly-owned subsidiary of Capital Holdings, was allocated a portion of the transmission projects by the PUCT under the CREZ program.  Lone Star's CREZ project includes constructing and operating approximately 300 miles of 345 kv transmission lines in Texas.  In 2010, the PUCT approve d Lone Star’s certificate of convenience and necessity, which both established Lone Star as a regulated transmission provider in Texas and granted approval to begin construction of Lone Star's CREZ project.  Lone Star is subject to the jurisdiction of the PUCT over a wide range of business activities, including, among others, rates charged to customers and certain aspects of siting, construction and operation of transmission systems.  The PUCT has the authority to disallow recovery of costs that it considers excessive or impudently incurred.  In late 2010, Lone Star commenced right-of-way acquisition and early construction activities on its CREZ project and expects the transmission line to be placed in service in 2013.

At December 31, 2010, NextEra Energy's investment in Lone Star totaled approximately $20 million. Lone Star invested approximately $20 million during 2010 and plans to invest a total of approximately $780 million, including AFUDC, during the period 2011 through 2014 for construction of the transmission line.

ENVIRONMENTAL MATTERS

NextEra Energy and FPL are subject to domestic and foreign environmental laws and regulations, including extensive federal, state, and local environmental statutes, rules, and regulations relating to air and water quality, land use, power plant and transmission line siting, EMF from power lines and substations, oil discharge from transformers, lead paint, asbestos, noise and aesthetics, solid waste, natural resources, wildlife mortality and other environmental matters.  Compliance with these laws and regulations increases the cost of electric service by requiring, among other things, changes in the design and operation of existing facilities and changes or delays in the location, design, construction and operation of new facilities.  Environmental laws and regulations are subject to change.  The following is a discussion of emerging federal and state initiatives and rules that could potentially affect NextEra Energy and its subsidiaries, including FPL and NextEra Energy Resources.

Climate Change - The U.S. Congress and certain states and regions continue to consider several legislative and regulatory proposals with respect to GHG emissions.  The economic and operational impact of climate change legislation on NextEra Energy and FPL depends on a variety of factors, including, but not limited to, the allowed emissions, whether emission allowances will be allocated or auctioned, the cost to reduce emissions or buy allowances in the marketplace and the availability of offsets and mitigating factors to moderate the costs of compliance.  If and until legislation is enacted and implementing regulations are adopted, the economic and operational impact (either positive or negative) on NextEra Energy and FPL cannot be determined, but could be ma terial.

Meanwhile, the EPA is implementing regulatory action under the Clean Air Act to address climate change.  In 2009, the EPA issued a final endangerment finding under Section 202(a) of the Clean Air Act that the current and projected concentrations of GHG in the atmosphere threaten the public health and welfare of current and future generations.  The final finding noted that, among other things, climate change is expected to result in an increase in electricity demand, especially supply for peak demand, a potentially adverse impact on hydropower resources as well as the potential risk of serious adverse effects on energy infrastructure from extreme weather events.  In April 2010, the EPA and the U.S. Department of Transportation issued a final rule under the Clean Air Act to regulate GHG emissions from light duty vehicles.  The final light duty vehicle rule applies to new passenger vehicles effective January 2011 which triggers certain permitting requirements under the Clean Air Act for any new or modified stationary sources of GHG, including power plants, that exceed certain GHG emissions levels. In May 2010, the EPA released a final rule under the Clean Air Act to tailor requirements for GHG emissions which increased applicability thresholds for major sources of GHG emissions.  New facilities emitting 100,000 tons per year (tpy) or more of GHG and modifications to existing facilities resulting in an increase of GHG emissions of 75,000 tpy or more will have to perform a Best Available Control Technology review and, based on that review, may have to add additional emissions control equipment or implement energy efficiency projects.  Several petitioners have challenged the EPA’s GHG regulations and requested a stay of the rules which the D.C. Circuit denied in December 20 10.  The case is pending review by the D.C. Circuit; the timing and ultimate outcome of which is uncertain at this time.  In December 2010, the EPA announced that it will propose New Source Performance Standards (NSPS) for both new or modified boilers and for existing facilities no earlier than July 2011.  The EPA plans to finalize the NSPS by May 2012.

In 2009, the EPA issued a final rule for mandatory reporting of GHG emissions from facilities with emissions of 25,000 tpy or more, which includes all of FPL's and NextEra Energy Resources' fossil plants.  Affected facilities began collecting data in January 2010 and the first emissions report is due March 31, 2011 for the 2010 period.  In December 2010, the EPA issued a final rule governing electrical transmission and distribution equipment use which requires owners/operators of electric power transmission and distribution equipment that contains a threshold volume of sulfurhexaflouride and/or perfluorocarbons to monitor such emissions from electric power transmission and distribution systems.  Affected operators, including FPL, began collecting data in January 2011 and the first emissions report is due March 31, 2012 for the 2011 period.

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Based on the most recent reference data available from government sources, NextEra Energy is among the lowest emitters, among electric generators, of GHG in the United States measured by its rate of emissions expressed as pounds of carbon dioxide (CO2) per megawatt-hour (mwh) of generation.  However, the legislative and regulatory proposals have differing methods of implementation and the impact on FPL's and NextEra Energy Resources' generating units and/or the financial impact (either positive or negative) to NextEra Energy and FPL could be material, depending on the eventual structure of any legislation enacted or specific implementation rules adopted.

In anticipation of the potential for further imposition of GHG emission limits on the electric industry in the future, NextEra Energy has taken a leadership role in the debate of climate change regulation and is involved in several climate change initiatives, including, but not limited to, the following:

· voluntary reporting of its GHG emissions and climate change strategy through the Carbon Disclosure Project (an investor-led initiative to identify climate change impacts on publicly-traded companies);

· participation in the U.S. Climate Action Partnership (an alliance made up of a diverse group of U.S.-based businesses and environmental organizations, which in January 2009 issued the Blueprint for Legislative Action, a set of legislative principles and recommendations to address global climate change and the reduction of GHG emissions);

· participation in the Clinton Global Initiative (an organization which seeks to foster shared commitment by individuals, businesses and governments to confront major world issues and achieve real change);

· participated in the EPA's Climate Leaders Program to reduce GHG intensity in the United States 18% by 2012, including reporting of emissions data annually.  During 2008, NextEra Energy met its commitment to achieve a 2008 target emissions rate reduction of 18% below a 2001 baseline emission rate measured in pounds per mwh.  This program was discontinued in 2009 by the EPA in response to the EPA's mandatory GHG reporting rule requirement;

· supporting Edison Electric Institute's climate change framework, which supports the concept of mandatory legislation capping carbon emissions economy wide and recommends, among other things, an 80% reduction of carbon emissions from current levels by 2050; and

· focusing on customer energy efficiency and conservation through programs such as Energy Smart Florida and EarthEra Renewable Energy Trust.

NextEra Energy Resources' plants operate in many states and regions that have developed or are in the process of developing legislation to reduce GHG emissions, including, but not limited to, the following:

· RPS, currently in place in approximately 30 states and the District of Columbia, require electricity providers in the state or district to meet a certain percentage of their retail sales with energy from renewable sources.  These standards vary, but the majority include requirements to meet 10% to 25% of the electricity providers' retail sales with energy from renewable sources by 2025.

· The Regional Greenhouse Gas Initiative (RGGI) is a GHG reduction initiative whereby ten Northeast and Mid-Atlantic member states have enacted laws and adopted regulations that establish a cap-and-trade program for covered electric generating units in Connecticut, Delaware, Maine, New Hampshire, New Jersey, New York, Vermont, Maryland, Massachusetts and Rhode Island.  RGGI members have agreed to stabilize power plant CO2 emissions at 2009 levels through the end of 2014 and to further reduce the sector's emissions another 10% by the end of 2018.  The RGGI GHG reduction requirements affect 12 NextEra Energy Resources' fossil electric generating units, requiring those electric generating units to reduce emissions or to acquire CO2 allowances for emis sions of CO2.  Based on NextEra Energy Resources' clean generating portfolio in the RGGI marketplace, NextEra Energy Resources experienced a positive impact on earnings in 2009 and 2010 and expects that the requirements will have a positive overall impact on NextEra Energy Resources' earnings in 2011.  In the fourth quarter of 2010, the RGGI participating states began efforts to support the 2012 program review called for in the RGGI Memorandum of Understanding, which will be a comprehensive evaluation including program success, program impacts, additional reductions, electricity imports and associated emissions leakage, and offsets.

· The Western Climate Initiative (WCI) is a GHG reduction initiative with a goal of reducing CO2 emissions by 15% below 2005 levels by 2020 for participants (Arizona, California, Oregon, Montana, New Mexico, Washington and Utah, as well as British Columbia, Manitoba, Ontario and Quebec, Canada).  Due to concerns about the economic impacts of GHG reductions programs, some states and provinces are reconsidering their commitment to the WCI.

· California Greenhouse Gas Regulation (CGGR) - California has enacted legislation to reduce GHG emissions in the state to 1990 emissions levels by 2020.  In December 2010, pursuant to the legislation, the California Air Resources Board approved a multi-sector GHG cap-and-trade program along with other GHG reduction measures which will begin in 2012.  Based on NextEra Energy Resources' clean generating portfolio in California, the impact of complying with the CGGR is not expected to have a material adverse impact on the financial statements of NextEra Energy.

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Clean Air Act Mercury/Nickel Rule - Since 2005, the EPA has made several attempts to regulate nickel emissions from oil-fired generating units and mercury emissions from coal-fired generating units.  In 2008, the D.C. Circuit required the EPA to proceed with rulemaking under Section 112 of the Clean Air Act to promulgate a Utility Maximum Achievable Control Technology (MACT) rule by November 2011 requiring reductions of hazardous air pollutants from coal-fired and oil-fired generating units' emissions.  Depending upon the final outcome of the EPA's rulemaking, it is possible that certain oil-fired and coal-fired units at FPL and NextEra Energy Resources may be required to add additional pollution control equipment.

Clean Air Interstate Rule (CAIR)/Clean Air Transport Rule (Transport Rule) - In 2005, the EPA published a final CAIR that requires sulfur dioxide (SO2) and nitrogen oxide (NOx) emissions reductions from electric generating units in 28 states, where the emissions from electric generating units are deemed to be transported to downwind states.  In 2008, the D.C. Circuit found significant flaws in the rule and remanded it back to the EPA for further rulemaking.  Because the D.C. Circuit chose not to vacate the rule, NextEra Energy and FPL were required to begin complying with the current version of the CAIR on January 1, 2009 and must continue to comply until the EPA rewrites the rule.   In July 2010, the EPA released the proposed rewrite of the CAIR, known as the Transport Rule, to limit emissions of SO2 and NOx from power plants in 31 eastern states and the District of Columbia and provides for a new allocation methodology for emission allowances and revised emissions reduction limits beginning in 2012.  NextEra Energy has submitted comments on the Transport Rule to the EPA and the final rule is expected to be published no earlier than the summer of 2011.  The impact of complying with the current version of the CAIR has not had, and, along with compliance with the Transport Rule as currently proposed, is not expected to have, a material adverse effect on the financial statements of NextEra Energy and FPL.

Clean Air Visibility Rule - In 2005, the EPA issued the Clean Air Visibility Rule to address regional haze in areas which include certain national park and wilderness areas through the installation of BART for electric generating units.  BART eligible units include those built between 1962 and 1977 that have the potential to emit more than 250 tons of visibility-impairing pollution per year.  The rule requires states to complete BART determinations and allows for a five-year period to implement pollution controls.  The final BART requirements of the Clean Air Visibility Rule affect FPL's Turkey Point Fossil Units Nos. 1 and 2 and one of NextEra Energy Resources' units located in Maine and are not expected to have a material adverse effect on th e financial statements of NextEra Energy or FPL.

In 2007, the FDEP began the process to expand the number of units covered under the "Reasonable Further Progress" provision of the Clean Air Visibility Rule in an effort to reduce emissions of SO2 in areas which include certain national park and wilderness areas.  In 2010, the FDEP rescinded the “Reasonable Further Progress” provision from Florida's plan to address regional haze and instead will rely on the EPA’s Transport Rule and proposed boiler MACT rules to demonstrate reasonable progress toward the visibility goals for national park and wilderness areas.

Clean Water Act Section 316(b) - In 2004, the EPA issued a rule under Section 316(b) of the Clean Water Act to address the location, design, construction and capacity of intake structures at existing power plants with once-through cooling water systems.  The rule would have required NextEra Energy to install controls or implement operational changes to reduce the impact on aquatic organisms from such water intake systems.  A number of environmental groups and six northeastern states appealed the rule and, in 2007, the U.S. Court of Appeals for the Second Circuit issued a decision eliminating several of the compliance alternatives, including the use of a "cost-benefit test" and restoration measures, from consideration and remanded the rule to the EPA for furth er rulemaking.  In 2009, the U.S. Supreme Court ruled that the use of a cost-benefit test is an acceptable alternative under Section 316(b) of the Clean Water Act for determining the best technology available for minimizing impacts to aquatic organisms from the use of large cooling water intake systems.  The EPA is working on new rulemaking which is not expected to be proposed before the spring of 2011 with the final rule in the summer of 2012.  Depending upon the final outcome of the rulemaking by the EPA, eight of FPL's generating facilities (Cape Canaveral, Cutler, Fort Myers, Lauderdale, Port Everglades, Sanford, Riviera and St. Lucie) and three NextEra Energy Resources plants (Seabrook, Point Beach and an oil-fired plant in Maine) may be required to add additional controls or make operational changes to comply with the rule, the economic and operational impact of which cannot be determined at this time, but could be material.  Prior to the passage of a new rule, s tates are continuing to utilize “Best Professional Judgment” in the application of Section 316(b) compliance requirements.  Through December 31, 2010, five FPL facilities undergoing permit renewals have been or may be required to install fish impingement controls with fish return systems.

Revisions to the National Ambient Air Quality Standards (NAAQS) for Ozone - In 2008, the EPA issued a final rule establishing a new standard for ground-level ozone at 75 parts per billion (ppb).  After reconsideration, in January 2010, the EPA issued a proposed revision to the NAAQS for ground-level ozone requesting comments on revising the 2008 primary standard to a more restrictive primary standard of between 60 ppb and 70 ppb. It is anticipated that the EPA will issue a final rule no earlier than the summer of 2011 which will require states to (i) identify areas which will be designated as non-attainment for ground-level ozone within 120 days of the final rule, (ii) develop plans to meet the attainment standard by 2013 and (iii) begin meeting the attainment sta ndard between 2014 and 2031 based on non-attainment severity. Generating facilities affected by the new ozone standard may be required to install additional pollution control equipment.  A review of recent ozone monitoring data indicates that some or all of FPL's generating facilities may be located in non-attainment areas, or areas projected to be in non-attainment depending on the primary standard adopted, and some of those generating facilities may be required to install additional pollution control equipment.

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EXECUTIVE OFFICERS OF NEXTERA ENERGY(a)

Name	Age	Position	Effective Date
Christopher A. Bennett	52	Executive Vice President & Chief Strategy, Policy & Business Process Improvement Officer of NextEra Energy	February 15, 2008(b)
Paul I. Cutler	51	Treasurer of NextEra Energy Treasurer of FPL Assistant Secretary of NextEra Energy and FPL	February 19, 2003 February 18, 2003 December 10, 1997
F. Mitchell Davidson	48	Chief Executive Officer of NextEra Energy Resources President of NextEra Energy Resources	July 29, 2008 December 15, 2006
Moray P. Dewhurst	55	Vice Chairman and Chief of Staff of NextEra Energy	August 17, 2009
Shaun J. Francis	39	Executive Vice President, Human Resources of NextEra Energy Executive Vice President, Human Resources of FPL	August 16, 2010 January 31, 2011
Chris N. Froggatt	53	Vice President of NextEra Energy Controller and Chief Accounting Officer of NextEra Energy	October 19, 2009 February 27, 2010
Lewis Hay, III	55	Chief Executive Officer of NextEra Energy Chairman of NextEra Energy and FPL	June 11, 2001 January 1, 2002
Joseph T. Kelliher	50	Executive Vice President, Federal Regulatory Affairs of NextEra Energy	May 18, 2009
Robert L. McGrath	57	Executive Vice President, Engineering, Construction & Corporate Services of NextEra Energy and FPL	February 21, 2005(b)
Manoochehr K. Nazar	56	Executive Vice President, Nuclear Division and Chief Nuclear Officer of NextEra Energy Executive Vice President, Nuclear Division and Chief Nuclear Officer of FPL	January 1, 2010 January 15, 2010
Armando J. Olivera	61	Chief Executive Officer of FPL President of FPL	July 17, 2008 June 24, 2003
Armando Pimentel, Jr.	48	Chief Financial Officer of NextEra Energy and FPL Executive Vice President, Finance of NextEra Energy and FPL	May 3, 2008 February 15, 2008(b)
James L. Robo	48	President and Chief Operating Officer of NextEra Energy	December 15, 2006
Antonio Rodriguez	68	Executive Vice President, Power Generation Division of NextEra Energy Executive Vice President, Power Generation Division of FPL	January 1, 2007(b) July 1, 1999(b)
Charles E. Sieving	38	Executive Vice President & General Counsel of NextEra Energy Executive Vice President of FPL Assistant Secretary of NextEra Energy	December 1, 2008 January 1, 2009 May 21, 2010

¾¾¾¾¾¾¾¾¾¾

(a)

Information is as of February 24, 2011.  Executive officers are elected annually by, and serve at the pleasure of, their respective boards of directors.  Except as noted below, each officer has held his present position for five years or more and his employment history is continuous.  Mr. Bennett was vice president, business strategy & policy of NextEra Energy from July 2007 to February 2008.  From September 1995 to June 2007, Mr. Bennett was vice president of Dean & Company, a management consulting and investment firm.  Mr. Davidson was senior vice president of business management of NextEra Energy Resources from March 2005 to December 2006.  Mr. Dewhurst was vice president, finance and chief financial officer of NextEra Energy and senior vice president, finance and chief financial officer of FPL from July 2001 to May 2008.  Mr. Francis was general manager of human resources for GE Transportation, a global technology leader and supplier to the railroad, marine, drilling, mining and wind power industries from February 2008 to August 2010.  From February 2006 to February 2008, Mr. Francis served as general manager of human resources of GE Equipment Services, a global technology leader in the transportation industry including rail cars, sea containers, tractor trailers, and Penske truck and leasing.  Mr. Froggatt was the vice president and treasurer of Pinnacle West Capital Corporation, a public utility holding company, and its major subsidiary, Arizona Public Service Company (APS), a regulated utility, from December 2008 to October 2009.  From October 2002 to December 2008, he was vice president, controller and chief accounting officer of APS.  Mr. Hay was also chief executive officer of FPL from January 2002 to July 2008.   Mr. Hay was president of NextEra Energy from June 2001 to December 2006.  Mr. Kelliher was chairman of the FERC from July 2005 to January 2009.  Mr. Nazar was the chief nuclear officer of NextEra Energy from January 2009 to December 2009.  He was senior vice president and chief nuclear officer of FPL from November 2007 to January 2009.  From October 2003 to November 2007, Mr. Nazar was senior vice president & chief nuclear officer of American Electric Power Company, Inc., a public utility holding company.  Mr. Pimentel was a partner of Deloitte & Touche LLP, an independent registered public accounting firm, from June 1998 to February 2008.  Mr. Robo was president of NextEra Energy Resources from July 2002 to December 2006.  He was also vice president, corporate development and strategy of NextEra Energy from March 2002 to December 2006.  Mr. Sieving was also general counsel of FPL from January 2009 to May 2010 .  Mr. Sieving was executive vice president, general counsel and secretary of PAETEC Holding Corp., a communications services and solutions provider, from February 2007 to November 2008 and was primarily responsible for all legal and regulatory matters.  Prior to that, Mr. Sieving was a partner in the corporate, securities and finance practice group of Hogan Lovells US LLP, an international law firm, with which he had been associated since October 1998.

(b)

NextEra Energy title changed from vice president to executive vice president effective May 23, 2008.  Where applicable, FPL title changed from senior vice president to executive vice president effective July 17, 2008.

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Item 1A.  Risk Factors

Risks Relating to NextEra Energy's and FPL's Business

The business, financial results, financial condition and prospects of NextEra Energy and FPL are subject to a variety of significant risks, many of which are beyond their control.  The following is a description of some of the important risk factors that may adversely affect the business and may cause the actual results of NextEra Energy and FPL in future periods to differ substantially from those that NextEra Energy or FPL currently expects or seeks.  Many of the risks set forth below may only apply to a portion of the businesses of subsidiaries of NextEra Energy, such as its FPL business, its wind or solar generation development businesses, its transmission business or its gas infrastructure business.  Accordingly, references to “NextEra Energy” below in some instances refer to the applicabl e businesses or subsidiaries of NextEra Energy.  Risks specifically applicable to FPL generally include a reference to “FPL.”

NextEra Energy’s and FPL’s financial results may be adversely affected by the extensive regulation of their businesses.

· The operations of NextEra Energy and FPL are subject to complex and comprehensive federal, state and other regulation.  This extensive regulatory framework, some but not all of which is more specifically identified in the following risk factors, regulates, among other things, NextEra Energy's and FPL's industry, rate and cost structure, operation of nuclear power facilities, construction and operation of generation, transmission and distribution facilities, acquisition, disposal, depreciation and amortization of assets and facilities, decommissioning costs, transmission reliability, wholesale and retail competition, and commodities trading and derivatives transactions.  In their business planning and in the management of their operations, NextEra Energy and FPL must address the effects of regulation on their businesses and proposed changes in the regulatory framework.  Significant changes in the nature of the regulation of NextEra Energy’s and FPL’s businesses could require changes to their business planning and management of their businesses and could adversely affect their financial results, including, but not limited to, the value of their assets.  NextEra Energy and FPL must periodically apply for licenses and permits from various local, state, federal and other regulatory authorities and abide by their respective conditions.  Should NextEra Energy or FPL be unsuccessful in obtaining necessary licenses or permits on acceptable terms, should there be a delay in obtaining or renewing necessary licenses or permits or should regulatory authorities initiate any investigations or enforcement actions or impose penalties or disallowances on NextEra Energy or FPL, NextEra Energy’s and FPL’s businesses could be adversely affected.

NextEra Energy’s and FPL’s financial results could be negatively affected if they or their rate-regulated businesses are unable to recover, in a timely manner, certain costs, a return on certain assets or an appropriate return on capital from customers through regulated rates and, in the case of FPL, cost recovery clauses.

· FPL is a regulated entity subject to the jurisdiction of the FPSC over a wide range of business activities, including, among other items, the retail rates charged to its customers, the terms and conditions of its services, procurement of electricity for its customers, issuance of securities, transfers of some utility assets and facilities to affiliates, and aspects of the siting and operation of its generating plants and transmission and distribution systems for the sale of electric energy.  Lone Star, which is a wholly-owned subsidiary of NextEra Energy, is a regulated entity subject to the jurisdiction of the PUCT over a wide range of business activities.  The FPSC and PUCT have the authority to disallow recovery by FPL and Lone Star, respectively, of costs that it considers excessive or imprudently incurred.  The regulatory process, which may be adversely affected by the politic al, regulatory and economic environment in Florida, Texas and elsewhere, can restrict NextEra Energy’s and FPL’s ability to grow earnings and does not provide any assurance as to achievement of authorized or other earnings levels.  NextEra Energy’s and FPL’s financial results could be materially adversely affected if any material amount of costs, a return on certain assets or an appropriate return on capital cannot be recovered through base rates, cost recovery clauses or other regulatory mechanisms.

· Decisions of the FPSC and the PUCT have been and, in the future, may be adversely affected by the local and national political, regulatory and economic environment and may adversely affect the financial results of NextEra Energy and FPL.  These decisions may require, for example, NextEra Energy or FPL to cancel or delay planned development activities and to reduce or delay other planned capital expenditures which could reduce the earnings potential of NextEra Energy and FPL.

NextEra Energy and FPL are subject to federal regulatory compliance and proceedings which have significant compliance costs and expose them to substantial monetary penalties and other sanctions.

· In addition to the regulatory risks that may affect NextEra Energy and FPL described above, the extensive federal regulation of the operations of NextEra Energy and FPL exposes the companies to significant and increasing compliance costs.  NextEra Energy and FPL also are subject to costs and other potentially adverse effects of regulatory investigations, proceedings, settlements, decisions and claims, including, among other items, potentially significant monetary penalties for non-compliance.  As an example, under the Energy Policy Act of 2005, NextEra Energy and FPL, as owners and operators of bulk power transmission systems and/or electric generation facilities, are subject to mandatory reliability standards.  Compliance with these mandatory reliability standards may subject NextEra Energy and FPL to higher operating costs and may result in increased capital expenditures. &# 160;If FPL or NextEra Energy is found not to be in compliance with these standards, it may incur substantial monetary penalties and other sanctions.

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NextEra Energy and FPL may be adversely affected by increased governmental and regulatory scrutiny or negative publicity.

· From time to time, political and public sentiment may result in a significant amount of adverse press coverage and other adverse public statements affecting NextEra Energy and FPL.  Adverse press coverage and other adverse statements may result in investigations by regulators, legislators and law enforcement officials or in lawsuits.  Responding to these investigations and lawsuits, regardless of the ultimate outcome of the proceeding, can divert the time and effort of senior management from NextEra Energy’s and FPL’s businesses.  Addressing any adverse publicity, governmental scrutiny or enforcement or other legal proceedings is time consuming and expensive and, regardless of the factual basis for the assertions being made, can also have a negative impact on the reputation of NextEra Energy and FPL and on the morale and performance of their employees, which could adver sely affect their financial results.

NextEra Energy’s and FPL’s businesses are subject to risks associated with legislative and regulatory initiatives.

· NextEra Energy and FPL operate in a changing market environment influenced by various legislative and regulatory initiatives, including, for example, initiatives regarding regulation, deregulation or restructuring of the energy industry and regulation of the commodities trading and derivatives markets.  NextEra Energy and its subsidiaries will need to adapt to any changes and may face increasing costs and competitive pressures in doing so.  NextEra Energy produces the majority of its electricity from clean and renewable fuels, such as nuclear, natural gas and wind, operates in the competitive segment of the electric industry, has targeted the competitive segments of the electric industry for some of its future growth and relies on the efficient operation of the commodities trading and derivatives markets.  NextEra Energy’s financial results and growth prospects could be adver sely affected as a result of new, or changes in, laws, regulations or interpretations, or other regulatory initiatives, including, but not limited to, those that reverse or restrict the competitive restructuring of the energy industry or the effective operation of the commodities trading or derivatives markets.

NextEra Energy 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.

· NextEra Energy and FPL are subject to domestic and foreign environmental laws and regulations, including, but not limited to, extensive federal, state, and local environmental statutes, rules and regulations relating to air quality, water quality and usage, climate change, GHG, including, but not limited to, CO2 emissions, waste management, hazardous wastes, marine, avian and other wildlife mortality and habitat protection, natural resources, health, safety and RPS that could, among other things, prevent or delay the development of power generation, power or natural gas transmission, or other infrastructure projects, restrict the output of some existing facilities, limit the use of some fuels required for the production of electricity, require additional pollution control equipment, and otherwise increase costs or limit or eliminate certa in operations.  There are significant capital, operating and other costs associated with compliance with these environmental statutes, rules and regulations, and those costs could be even more significant in the future as a result of new legislation, the current trend toward more stringent standards, and stricter and more expansive application of existing environmental regulations.  For example, among other potential or pending changes described elsewhere in this report, the process of hydraulic fracturing or similar technologies to drill for natural gas and related compounds used by NextEra Energy's gas infrastructure business are currently being debated for potential regulation at the state and federal levels.  Violations of current or future laws, rules and regulations could expose NextEra Energy and FPL to regulatory proceedings, disputes with, and legal challenges by, third parties, and potentially significant civil fines, criminal penalties and other sanctions.

NextEra Energy’s and FPL’s businesses could be negatively affected by federal or state laws or regulations mandating new or additional limits on the production of GHG emissions.

· Federal or state laws or regulations may be adopted that would impose new or additional limits on GHG, including, but not limited to, CO2 and methane, from electric generating units storing and combusting fossil fuels like coal and natural gas.  The potential effects of such GHG emission limits on NextEra Energy’s and FPL’s electric generating units are subject to significant uncertainties based on, among other things, the timing of the implementation of any new requirements, the required levels of emission reductions, the nature of any market-based or tax-based mechanisms adopted to facilitate reductions, the relative availability of GHG emission reduction offsets, the development of cost-effective, commercial-scale carbon capture and storage technology and supporting regulations and liability mitigation measures, a nd the range of available compliance alternatives.  While NextEra Energy’s and FPL’s electric generating units emit GHGs at a lower rate of emissions than most of the U.S. electric generation sector, the financial results of NextEra Energy and FPL could be adversely affected to the extent that any new GHG emission limits, among other potential impacts:

·      create substantial additional costs in the form of taxes or emission allowances;

· make some of NextEra Energy’s and FPL’s electric generating units uneconomical to operate in the long term;

· require significant capital investment in carbon capture and storage technology, fuel switching, or the replacement of high-emitting generation facilities with lower-emitting generation facilities; or

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· affect the availability or cost of fossil fuels.

The construction, operation and maintenance of nuclear generation facilities involve risks that could result in fines or the closure of nuclear generation facilities owned by NextEra Energy or FPL and in increased costs and capital expenditures.

· Together, FPL and NextEra Energy’s other subsidiaries own, or hold undivided interests in, eight nuclear generation units in four states.  The construction, operation and maintenance of the facilities involve inherent risks, including, but not limited to, the following:

· The nuclear generation facilities are subject to environmental, health and financial risks, such as risks relating to site storage of spent nuclear fuel, the disposition of spent nuclear fuel, leakage and emissions of tritium and other radioactive elements in the event of a nuclear accident or otherwise, the threat of a terrorist attack and other potential liabilities arising out of the ownership or operation of the facilities.  Although NextEra Energy and FPL maintain decommissioning funds and external insurance coverage which are intended to reduce the financial exposure to some of these risks, the cost of decommissioning the facilities could exceed the amount available in the decommissioning funds, and the liability and property damages could exceed the amount of insurance coverage.  In the event of an incident at any nuclear generation facility in the United States, NextEra Energy and FP L 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.

· The NRC has broad authority to impose licensing and safety-related requirements for the construction of nuclear generation facilities, the addition of capacity at existing nuclear generation facilities, and the operation and maintenance of nuclear generation facilities, and such requirements are subject to change.  In the event of non-compliance, the NRC has the authority to impose fines or shut down a nuclear generation facility, or to take both of these actions, depending upon its assessment of the severity of the situation, until compliance is achieved.  NRC orders or new regulations related to increased security measures and any future safety requirements promulgated by the NRC could require NextEra Energy and FPL to incur substantial operating and capital expenditures at their nuclear generation facilities.  In addition, any serious nuclear incident occurring at a NextEra Ener gy or FPL plant could result in substantial remediation costs and other expenses.  A major incident at a nuclear facility anywhere in the world could cause the NRC to limit or prohibit the operation or licensing of any domestic nuclear generation facility.  An incident at a nuclear facility anywhere in the world also could cause the NRC to impose additional conditions or other requirements on the industry, which could increase costs and result in additional capital expenditures.

· The operating licenses for NextEra Energy’s and FPL’s nuclear generation facilities extend through at least 2030.  If any of NextEra Energy’s or FPL’s nuclear generation units cannot be operated through the end of their respective operating licenses, NextEra Energy or FPL may be required to increase depreciation rates, incur impairment charges and accelerate future decommissioning expenditures, which could adversely affect their financial results.

· Terrorist threats and increased public scrutiny of nuclear generation facilities could result in increased nuclear licensing or compliance costs which are difficult or impossible to predict.

NextEra Energy’s and FPL’s operating results could suffer if they do not proceed with projects under development or are unable to complete the construction of, or capital improvements to, generation, transmission, distribution or other facilities on schedule or within budget.

· NextEra Energy and FPL may incur significant costs for development of projects, including, but not limited to, preliminary engineering, permitting, legal and other expenses before it can be established whether a project is feasible, economically attractive, capable of being financed or, in some cases, approved for regulatory recoveries.  The ability of NextEra Energy and FPL to complete construction of, and capital improvement projects for, their generation, transmission, distribution, gas infrastructure and other facilities on schedule and within budget may be adversely affected by escalating costs for materials and labor and regulatory compliance, inability to obtain or renew necessary licenses, rights-of-way, permits or other approvals on acceptable terms, delays in obtaining or renewing necessary licenses, permits, rights-of-way and other approvals, disputes involving contractors, labor organizati ons, land owners and other third parties, negative publicity, transmission interconnection issues and other factors or failures.  If any development project or construction or capital improvement project is not completed or is delayed or subject to cost overruns, NextEra Energy's and FPL's operational and financial results may be adversely affected.  In any such event, among other matters, NextEra Energy and FPL could be subject to additional costs, which, in some cases, may not be approved for or recoverable through regulatory mechanisms, and could result in delay or termination payments and other damages under committed contracts, loss of tax credits and the write-off of their investment in the project.

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The operation and maintenance of power generation, transmission and distribution facilities involve significant risks that could adversely affect the financial results of NextEra Energy and FPL.

· The operation and maintenance of power generation, transmission and distribution facilities involve many risks, such as those identified elsewhere in these risk factors and those arising due to:

· risks of start-up operations;

· failures in the supply, availability or transportation of fuel;

· the impact of unusual or adverse weather conditions, including, but not limited to, natural disasters such as hurricanes, floods, earthquakes and droughts;

· performance below expected or contracted levels of output or efficiency;

· breakdown or failure of equipment, transmission and distribution lines or pipelines;

· availability of replacement equipment;

· risks of human injury from energized equipment;

· availability of adequate water resources and ability to satisfy water discharge requirements;

· inability to properly manage or mitigate known equipment defects throughout NextEra Energy’s and FPL’s generation fleets and transmission and distribution systems;

· use of new or unproven technology; and

· dependence on a specific fuel source.

The occurrence of any of these effects or events could result in, among other matters, lost revenues due to prolonged outages, increased expenses due to monetary penalties or fines, replacement equipment costs or an obligation to purchase or generate replacement power at potentially higher prices to meet contractual obligations.  Insurance, warranties or performance guarantees may not cover any or all of the lost revenues or increased expenses.  Breakdown or failure of an operating facility of NextEra Energy, for example, may prevent NextEra Energy from performing under applicable power sales agreements which, in some situations, could result in termination of the agreement or subject NextEra Energy to liability for liquidated damages.  The operation and maintenance of NextEra Energy’s gas infrastructure and power transmission businesses also are subject to many of the forego ing risks or substantially similar risks.

NextEra Energy’s competitive energy business is subject to development and operating risks that could limit the revenue growth of this business and have other negative effects on NextEra Energy’s financial results.

· To operate successfully in the competitive wholesale energy markets, NextEra Energy must, among other things, efficiently develop and operate its generating assets, procure adequate supplies of fuel and associated transportation at acceptable prices, successfully and timely complete project restructuring activities, maintain the qualifying facility status of certain projects and complete its energy deliveries in a timely manner.  Its ability to do so is subject to a variety of risks.  In addition to risks such as those identified elsewhere in these risk factors, risks that specifically affect NextEra Energy’s success in competitive wholesale markets and in the gas infrastructure business include:

· NextEra Energy may face increased competition, including, but not limited to, from other and new sources of power generation, excess generation capacity and shifting demand for power, legal and regulatory developments and general economic conditions.  Risks related to project siting, financing, construction, permitting, governmental approvals and the negotiation of project agreements may impede development activities.

· There can be significant volatility in market prices for fuel, electricity and renewable and other energy commodities.  NextEra Energy’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 NextEra Energy’s financial results.

· A portion of NextEra Energy’s power generation facilities operate wholly or partially without long-term power purchase agreements.  As a result, power from these facilities is sold on the spot market or on a short-term contractual basis, which may increase the volatility of NextEra Energy’s financial results.

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· NextEra Energy depends upon power transmission and natural gas transportation facilities owned and operated by others.  If transmission or transportation of sufficient power or natural gas is unavailable or disrupted, NextEra Energy’s ability to sell and deliver its wholesale power or natural gas may be limited.

NextEra Energy’s competitive energy business is dependent on continued public policy support and governmental support for renewable energy, particularly wind and solar projects.

· NextEra Energy’s competitive energy business, NextEra Energy Resources, depends heavily on government policies that support renewable energy and enhance the economic feasibility of developing wind and solar energy projects.  The federal government, a majority of the 50 U.S. states and portions of Canada and Spain provide incentives, such as tax incentives, RPS or feed-in tariffs, that support the sale of energy from renewable sources, such as wind and solar energy.  The applicable legislation often grants the relevant state public utility commission the ability to reduce electric supply companies’ obligations to meet the requirements in specified circumstances.  Any reduction or elimination of existing supportive policies, including, but not limited to, RPS or feed-in tariffs, and ultimately any failure to renew or increase existing supportive policies, could result in less demand for generation from NextEra Energy’s wind and solar energy projects.

· The Recovery Act includes, among other things, provisions that allow companies building wind facilities the option to choose among the following three investment cost recovery mechanisms: (1) PTCs which were extended for wind facilities placed in service prior to 2013, (2) ITCs of 30% of the cost for qualifying wind facilities placed in service prior to 2013, or (3) an election to receive a cash grant of 30% of the cost of qualifying wind facilities placed in service in 2009, 2010 or 2011, or if construction began prior to December 31, 2011 and the wind facility is placed in service prior to 2013.  An election to receive a cash grant of 30% in lieu of the 30% ITC also applies to the cost of qualifying solar facilities placed in service in either 2009, 2010 or 2011, or if construction began prior to December 31, 2011 and the solar facility is placed in service prior to 2017.  In ord er for NextEra Energy to continue to economically develop wind and solar energy projects in the future, it will need to utilize the investment cost recovery mechanisms currently available as well as requiring similar public policy support in the future.

NextEra Energy and FPL are subject to credit and performance risk from customers, counterparties and vendors.

· NextEra Energy and FPL are exposed to risks associated with the creditworthiness and performance of their customers, hedging counterparties and vendors under contracts for the supply of equipment, materials, fuel and other goods and services required for their business operations and for the construction and operation of, and for capital improvements to, their facilities.  Adverse conditions in the energy industry or the general economy, as well as circumstances of individual customers, counterparties and vendors, may affect the ability of some customers, counterparties and vendors to perform as required under their contracts.  If any counterparty or vendor fails to fulfill its contractual obligations, NextEra Energy and FPL may need to make arrangements with other counterparties or vendors, which could result in higher costs, untimely completion of power generation facilities and other proj ects, and/or a disruption of their operations.  If a defaulting counterparty is in poor financial condition, NextEra Energy and FPL may not be able to recover damages for any contract breach.

NextEra Energy’s and FPL’s financial results may continue to be negatively affected by slower customer growth and customer usage.

· NextEra Energy’s and FPL’s results of operations are affected by the growth in customer accounts and by customer usage, each of which directly influences the demand for electricity and the need for additional power generation and power delivery facilities.  A lack of growth or slower growth in the number of retail customers or in non-weather related customer usage, such as that which has occurred over the past several years, could adversely affect NextEra Energy’s and FPL’s results of operations.  Customer growth and customer usage are affected by a number of factors outside the control of NextEra Energy and FPL, such as mandated energy efficiency measures, demand side management goals, and economic and demographic conditions, such as population, job and income growth, housing starts and new business formation.  NextEra Energy’s and FPL’s financi al results may also be adversely affected by FPL’s ability to negotiate or renegotiate franchise agreements on acceptable terms with municipalities and counties in Florida.  As a result, NextEra Energy and FPL may make, but not fully realize the anticipated benefits from, significant investments and expenditures, which could adversely affect their financial results.

NextEra Energy’s and FPL’s financial results are subject to risks associated with weather conditions, such as the impact of severe weather.

· NextEra Energy’s and FPL’s financial results can be negatively affected by changes in the weather.  Weather conditions directly influence the demand for electricity and natural gas, affect the price of energy and energy-related commodities, and can affect the production of electricity at power generating facilities, including, but not limited to, wind, solar and hydro-powered facilities.  For example, the level of wind resource affects the results of operations of wind generating facilities.  Since the levels of wind, solar and hydro resources are variable and difficult to predict, NextEra Energy’s results of operations for individual wind, solar and hydro facilities vary or may vary significantly from period to period depending on the level of available resources.  To the extent that resources are not available at planned levels, the returns from these facilities may be less than expected.

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· In addition, NextEra Energy’s and FPL’s financial results would be affected by the impact of severe weather, such as hurricanes, floods and earthquakes, which can be destructive and cause power outages and property damage, reduce revenue, affect fuel supply, and require NextEra Energy and FPL to incur additional costs to restore service and repair damaged facilities.  As a company that provides electric service throughout most of the east and lower west coasts of Florida, FPL operates in an area that historically has been more prone to severe weather events, such as hurricanes.  A disruption or failure of electric generation, transmission or distribution systems or natural gas production, transmission, storage or distribution systems in the event of a hurricane, tornado, or other severe weather event, or otherwise, could prevent NextEra Energy and FPL from operating their busines ses in the normal course and could result in any of the adverse consequences described above.  At FPL and other regulated businesses of NextEra Energy, recovery of costs to restore service and repair damaged facilities is or may be subject to regulatory approval, and any determination by the regulator not to permit timely and full recovery of the costs incurred would result in a negative financial impact on NextEra Energy and FPL.

Disruptions, uncertainty or volatility in the credit and capital markets may negatively affect NextEra Energy’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 NextEra Energy and FPL and exert downward pressure on the market price of NextEra Energy’s common stock.

· NextEra Energy and FPL rely on access to capital and credit markets as significant sources of liquidity for capital requirements and other operations requirements that are not satisfied by operating cash flows.  Disruptions, uncertainty or volatility in those capital and credit markets, such as conditions that have existed in the recent past, could increase NextEra Energy’s and FPL’s cost of capital.  If NextEra Energy or FPL is unable to access regularly the capital and credit markets on terms that are reasonable, it may have to delay raising capital, issue shorter-term securities and incur an unfavorable cost of capital, which, in turn, could adversely affect its ability to grow its businesses and could contribute to lower earnings and reduced financial flexibility.  The market price and trading volume of NextEra Energy’s common stock are subject to fluctuations as a result of, among other factors, general stock market conditions and changes in market sentiment regarding the operations, business, growth prospects and financing strategies of NextEra Energy and its subsidiaries.

· Although NextEra Energy’s competitive energy subsidiaries have used non-recourse or limited-recourse, project-specific financing in the past, market conditions and other factors could adversely affectthe future availability of such financing.  The inability of NextEra Energy’s subsidiaries to access the capital and credit markets to provide project-specific financing for electric-generating and other energy facilities on favorable terms, whether because of disruptions or volatility in those markets or otherwise, could necessitate additional capital raising or borrowings by NextEra Energy and/or Capital Holdings in the future.

· The inability of subsidiaries that have existing project-specific financing arrangements to meet the requirements of various agreements relating to those financings could give rise to a project-specific financing default which, if not cured or waived, might result in the specific project, and potentially in some limited instances its parent companies, being required to repay the associated debt or other borrowings earlier than otherwise anticipated, and if such repayment were not made, the lenders or security holders would generally have rights to foreclose against the project assets and related collateral, any of which actions could negatively affect NextEra Energy’s financial results, as well as the availability or terms of future financings for NextEra Energy or its subsidiaries.

NextEra Energy’s, Capital Holdings’ and FPL’s inability to maintain their current credit ratings may adversely affect NextEra Energy’s and FPL’s liquidity, limit the ability of NextEra Energy and FPL to grow their businesses, and increase interest costs, while the liquidity of the companies also could be impaired by the inability of their credit providers to maintain their current credit ratings or to fund their credit commitments.

· The inability of NextEra Energy, Capital Holdings and FPL to maintain their current credit ratings could adversely affect their ability to raise capital or obtain credit on favorable terms, which, in turn, could impact NextEra Energy’s and FPL’s ability to grow their businesses and service indebtedness and repay borrowings, and would likely increase their interest costs.  Some of the factors that can affect credit ratings are cash flows, liquidity, the amount of debt as a component of total capitalization, and political, legislative and regulatory actions.  There can be no assurance that one or more of the ratings of NextEra Energy, Capital Holdings and FPL will not be lowered or withdrawn entirely by a rating agency.

· The inability of NextEra Energy’s, Capital Holdings’ and FPL’s credit providers to maintain credit ratings acceptable under various agreements, or to fund their credit commitments, could require NextEra Energy, Capital Holdings or FPL, among other things, to renegotiate requirements in agreements, find an alternative credit provider with acceptable credit ratings to meet funding requirements, or post cash collateral.

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The use of derivative contracts by NextEra Energy and FPL in the normal course of business could result in financial losses or the payment of margin cash collateral that could adversely affect their financial results and liquidity.

· NextEra Energy and FPL use derivative instruments, such as swaps, options, futures and forwards, some of which are traded in the over-the-counter (OTC) markets or on exchanges, to manage their commodity and financial market risks, and for NextEra Energy to engage in trading and marketing activities.  NextEra Energy could recognize financial losses as a result of volatility in the market values of these derivative instruments or if a counterparty fails to perform or make payments under these derivative instruments.  NextEra Energy also could suffer a reduction in operating cash flows as a result of the requirement to post margin cash collateral.  In the absence of actively quoted market prices and pricing information from external sources, the valuation of these derivative instruments involves management’s judgment or use of estimates.  Although NextEra Energy and FP L execute transactions in derivative instruments on either recognized exchanges or via the OTC markets, depending on the most favorable credit and market execution factors, there is greater volatility and less liquidity in transactions executed in OTC markets and, as a result, NextEra Energy and FPL may not be able to execute such transactions in times of market volatility.  As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these derivative instruments.  In addition, FPL’s use of such instruments could be subject to prudence challenges and, if found imprudent, could result in disallowances of cost recovery for such use by the FPSC.

· NextEra Energy provides full energy and capacity requirement services, which include, for example, load-following services and various ancillary services, primarily to distribution utilities to satisfy all or a portion of such utilities’ power supply obligations to their customers.  The supply costs for these transactions may be affected by a number of factors, including, but not limited to, events that may occur after NextEra Energy has committed to supply power, such as weather conditions, fluctuating prices for energy and ancillary services, and the ability of the distribution utilities’ customers to elect to receive service from competing suppliers.  If the supply costs are not favorable, NextEra Energy’s operating costs could increase and adversely affect its results of operations.

· NextEra Energy is an active participant in energy markets.  The liquidity of regional energy markets is an important factor in the company's ability to manage risks in these operations.  Over the past several years, other market participants have ceased or significantly reduced their activities in energy markets as a result of several factors, including, but not limited to, government investigations, changes in market design, and deteriorating credit quality.  Liquidity in the energy markets can be adversely affected by price volatility, restrictions on the availability of credit, and other factors.  As a result, reductions in liquidity may restrict the ability of NextEra Energy to manage its risks, and this could negatively affect NextEra Energy’s financial results.

· NextEra Energy and FPL have hedging and trading procedures and associated risk management tools, such as separate but complementary financial, credit, operational, compliance and legal reporting systems, internal controls, management review processes and other mechanisms, that may not work as planned.  Risk management tools and metrics such as daily value at risk, earnings at risk, stop loss limits and liquidity guidelines are based on historical price movements.  If price movements significantly or persistently deviate from historical behavior, the risk management tools may not protect against significant losses.  As a result of these and other factors, NextEra Energy and FPL cannot predict with precision the impact that risk management decisions may have on their financial results and liquidity.

NextEra Energy’s and FPL’s financial results and liquidity could be materially adversely affected if the rules implementing the Dodd-Frank Act broaden the scope of its provisions regarding the regulation of OTC financial derivatives and make them applicable to NextEra Energy and FPL.

· The Dodd-Frank Act was enacted into law in July 2010 which, among other things, provides for the regulation of the OTC derivatives market.  While the legislation is broad and detailed, substantial portions of the legislation require implementing rules to be adopted by federal governmental agencies including, but not limited to, the SEC and the U.S. Commodity Futures Trading Commission (CFTC).  NextEra Energy and FPL cannot predict the final rules that will be adopted to implement the OTC derivatives market provisions of the Dodd-Frank Act.  Those rules could negatively affect NextEra Energy’s and FPL’s ability to hedge their commodity and interest rate risks, which could have a material adverse effect on NextEra Energy’s and FPL’s financial results.  The rules also could require NextEra Energy Resources to restructure part of its energy marketing a nd trading operations or to discontinue certain portions of its business.  In addition, if the rules require NextEra Energy and FPL to post cash collateral with respect to swap transactions, NextEra Energy’s and FPL’s liquidity could be materially adversely affected, and their ability to enter into OTC derivatives to hedge commodity and interest rate risks could be significantly limited.  Reporting and compliance requirements of the rules also could significantly increase operating costs and expose NextEra Energy and FPL to penalties for non-compliance.

NextEra Energy’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.

· NextEra Energy is likely to encounter significant competition for acquisition opportunities that may become available as a result of the consolidation of the power industry in general.  In addition, NextEra Energy may be unable to identify attractive acquisition opportunities at favorable prices and to complete and integrate them successfully and in a timely manner.

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NextEra Energy 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 NextEra Energy or if NextEra Energy is required to perform under guarantees of obligations of its subsidiaries.

· NextEra Energy is a holding company and, as such, has no material operations of its own.  Substantially all of NextEra Energy’s consolidated assets are held by subsidiaries.  NextEra Energy’s ability to meet its financial obligations, including, but not limited to, its guarantees, and to pay dividends on its common stock is primarily dependent on the subsidiaries’ net income and cash flows, which are subject to the risks of their respective businesses, and their ability to pay upstream dividends or to repay funds to NextEra Energy.  The subsidiaries have financial obligations, including, but not limited to, payment of debt service, which they must satisfy before they can fund NextEra Energy.  NextEra Energy’s subsidiaries are separate legal entities and have no obligation to provide NextEra Energy with funds for its payment obligations.   In addition, the dividend-paying ability of some of the subsidiaries is limited by contractual restrictions which are contained in outstanding financing agreements and which may be included in future financing agreements.  The future enactment of laws or regulations also may prohibit or restrict the ability of NextEra Energy's subsidiaries to pay upstream dividends or to repay funds.  NextEra Energy guarantees many of the obligations of its consolidated subsidiaries, other than FPL, through guarantee agreements with Capital Holdings.  These guarantees may require NextEra Energy to provide substantial funds to its subsidiaries or their creditors or counterparties at a time when NextEra Energy is in need of liquidity to fund its own obligations or to pay dividends.  In addition, in the event of a subsidiary’s liquidation or reorganization, NextEra Energy’s right to participate in a distribution of assets is subject to the prior claims of the subsidiary’ s creditors.

Changes in tax laws, as well as judgments and estimates used in the determination of tax-related asset and liability amounts, could adversely affect NextEra Energy’s and FPL’s financial results, financial condition and liquidity.

· NextEra Energy’s and FPL’s provision for income taxes and reporting of tax-related assets and liabilities requires significant judgments and the use of estimates.  Amounts of tax-related assets and liabilities involve judgments and estimates of the timing and probability of recognition of income, deductions and tax credits, including, but not limited to, estimates for potential adverse outcomes regarding tax positions that have been taken and the ability to utilize tax benefit carryforwards, such as net operating loss and tax credit carryforwards.  Actual income taxes could vary significantly from estimated amounts due to the future impacts of, among other things, changes in tax laws, regulations and interpretations, financial condition and results of operations of NextEra Energy and its subsidiaries, including, but not limited to, FPL, as well as the resolution of audit issues r aised by taxing authorities.  Ultimate resolution of income tax matters may result in material adjustments to tax-related assets and liabilities which could negatively affect NextEra Energy’s and FPL’s financial results, financial condition and liquidity.

NextEra Energy’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 financial results of the retail business.

· NextEra Energy’s and FPL’sretail businesses require access to sensitive customer data in the ordinary course of business.  NextEra Energy’s and FPL’sretail businesses may also need to provide sensitive customer data to vendors and service providers who require access to this information in order to provide services, such as call center services, to the retail businesses.  If a significant breach occurred, the reputation of NextEra Energy and FPL could be adversely affected, customer confidence could be diminished, customer information could be used for identity theft purposes, NextEra Energy and FPL would be subject to costs associated with the breach and/or NextEra Energy and FPL could be subject to fines and legal claims, any of which may hav e a negative impact on the businesses and/or NextEra Energy’s and FPL’s financial results.

A failure in NextEra Energy’s and FPL’s operational systems or infrastructure, or those of third parties, could impair their liquidity, disrupt their businesses, result in the disclosure of confidential information and adversely affect their financial results.

· NextEra Energy’s and FPL’s businesses are highly dependent on their ability to process and monitor, on a daily basis, a very large number of transactions, many of which are highly complex, and cross numerous and diverse markets.  Due to the size, scope and geographical reach of NextEra Energy’s and FPL’s businesses, and due to the complexity of the process of power generation, transmission and distribution, the development and maintenance of NextEra Energy’s and FPL’s operational systems and infrastructure is challenging.  NextEra Energy's and FPL’s operating systems and facilities may fail to operate properly or become disabled as a result of events that are either within, or wholly or partially outside, their control, such as operator error, severe weather or terrorist activities.  Any such failure or disabling event could adversely affec t NextEra Energy’s and FPL’s ability to process transactions and provide services, and their financial results and liquidity.

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· NextEra Energy and FPL add, modify and replace information systems on a regular basis.  Modifying existing information systems or implementing new or replacement information systems is costly and involves risks, including, but not limited to, integrating the modified, new or replacement system with existing systems and processes, implementing associated changes in accounting procedures and controls, and ensuring that data conversion is accurate and consistent.  Any disruptions or deficiencies in existing information systems, or disruptions, delays or deficiencies in the modification or implementation of new information systems, could result in increased costs, the inability to track or collect revenues, the diversion of management’s and employees’ attention and resources, and could negatively impact the effectiveness of the companies’ control environment, and/or the compani es’ ability to timely file required regulatory reports.

· NextEra Energy and FPL also face the risks of operational failure, termination, or capacity constraints of third parties, including, but not limited to, those who provide power transmission and natural gas transportation services.

Threats of terrorism and catastrophic events that could result from terrorism, cyber attacks, or individuals and/or groups attempting to disrupt NextEra Energy’s and FPL’s businesses, or the businesses of third parties, may impact the operations of NextEra Energy and FPL in unpredictable ways and could adversely affect NextEra Energy’s and FPL’s financial results and liquidity.

· NextEra Energy and FPL are subject to the potentially adverse operating and financial effects of terrorist acts and threats, as well as cyber attacks and other disruptive activities of individuals or groups.  NextEra Energy’s and FPL’s generation, transmission and distribution facilities, fuel storage facilities, information technology systems and other infrastructure facilities and systems and physical assets, could be direct targets of, or indirectly affected by, such activities.  Terrorist acts or other similar events could harm NextEra Energy’s and FPL’s businesses by limiting their ability to generate, purchase or transmit power and by delaying their development and construction of new generating facilities and capital improvements to existing facilities.  These events, and governmental actions in response, could result in a material decrease in revenue s and significant additional costs to repair and insure NextEra Energy’s and FPL’s assets, and could adversely affect NextEra Energy’s and FPL’s operations by contributing to disruption of supplies and markets for natural gas, oil and other fuels.  They could also impair NextEra Energy’s and FPL’s ability to raise capital by contributing to financial instability and lower economic activity.

· NextEra Energy and FPL operate in a highly regulated industry that requires the continued operation of sophisticated information technology systems and network infrastructure.  Despite NextEra Energy’s and FPL’s implementation of security measures, all of their technology systems are vulnerable to disability, failures or unauthorized access due to such activities.  If NextEra Energy’s or FPL’s technology systems were to fail or be breached and be unable to recover in a timely way, NextEra Energy and FPL would be unable to fulfill critical business functions, and sensitive confidential and other data could be compromised, which could have a material adverse effect on NextEra Energy’s and FPL’s financial results.

· The implementation of security guidelines and measures and maintenance of insurance, to the extent available, addressing such activities could increase costs.  These types of events could materially adversely affect NextEra Energy’s and FPL’s financial results.  In addition, these types of events could require significant management attention and resources, and could adversely affect NextEra Energy’s and FPL’s reputation among customers and the public.

· A disruption of the regional electric transmission grid, natural gas pipeline infrastructure or other fuel sources, could negatively impact NextEra Energy’s and FPL’s businesses.  Because generation, transmission systems and natural gas pipelines are part of an interconnected system, NextEra Energy and FPL face the risk of possible loss of business due to a disruption caused by the impact of an event on the interconnected system (such as severe weather or a generator or transmission facility outage, pipeline rupture, or a sudden and significant increase or decrease in wind generation) within NextEra Energy’s and FPL’s systems or within a neighboring system.  Any such disruption could have a material adverse effect on NextEra Energy’s and FPL’s financial results.

The ability of NextEra Energy 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. NextEra Energy’s and FPL’s insurance coverage may not provide protection against all significant losses.

· The ability of NextEra Energy and FPL to obtain insurance, as well as the cost and coverage of such insurance, could be affected by developments affecting their businesses, as well as by international, national, state or local events, as well as the financial condition of insurers.  Insurance coverage may not continue to be available at all or at rates or on terms similar to those presently available to NextEra Energy and FPL.  A loss for which NextEra Energy and FPL are not fully insured could materially and adversely affect their financial results.  NextEra Energy’s and FPL’s insurance may not be sufficient or effective under all circumstances and against all hazards or liabilities to which the companies may be subject.

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The businesses and financial results of NextEra Energy and FPL could be negatively affected by the lack of a qualified workforce, work strikes or stoppages and increasing personnel costs.

· NextEra Energy and FPL may not be able effectively and profitably to obtain new customers, or grow their customer base, service existing customers and meet their other business plan goals if they do not attract and retain a qualified workforce.  The lack of a qualified workforce, including, for example, the loss or retirement of key executives and other employees, may adversely affect service and productivity and contribute to higher training and safety costs.  Over the next several years, a significant portion of NextEra Energy’s and FPL’s workforce, including, but not limited to, many workers with specialized skills maintaining and servicing the nuclear generation facilities and electrical infrastructure, will be eligible to retire.  Such highly skilled individuals may not be able to be replaced quickly due to the technically complex work they perform.  Pers onnel costs also may increase due to inflationary or competitive pressures on payroll and benefits costs and revised terms of collective bargaining agreements with union employees.  Employee strikes or work stoppages could disrupt operations and lead to a loss of customers and revenue.

Poor market performance and other economic factors could affect NextEra Energy’s and FPL’s nuclear decommissioning funds’ asset value or defined benefit pension plan’s funded status, which may adversely affect NextEra Energy’s and FPL’s liquidity and financial results.

· NextEra Energy and FPL are required to maintain decommissioning funds to satisfy their future obligations to decommission their nuclear power plants.  In addition, NextEra Energy sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NextEra Energy and its subsidiaries.  A decline in the market value of the assets held in the decommissioning funds or in the defined benefit pension plan due to poor investment performance or other factors may increase the funding requirements for these obligations.  Moreover, NextEra Energy’s and FPL’s defined benefit pension plan is sensitive to changes in interest rates, since, as interest rates decrease the funding liabilities increase, potentially increasing benefits costs and funding requirements.  Any increase in benefits costs or funding requirements may have an adverse effect on NextEra Energy’s and FPL’s liquidity and financial results.

Increasing costs associated with health care plans may adversely affect NextEra Energy's and FPL's financial results.

· The costs of providing health care benefits to employees and retirees have increased substantially in recent years.  NextEra Energy and FPL believe that their employee benefit costs, including, but not limited to, costs related to health care plans for employees and former employees, will continue to rise.  The increasing costs and funding requirements associated with NextEra Energy's and FPL's health care plans may adversely affect the companies' financial results.

The factors described above, as well as other information set forth in this report, which could materially adversely affect NextEra Energy's and FPL's businesses, financial condition, future financial results and/or liquidity should be carefully considered.  The risks described above are not the only risks facing NextEra Energy and FPL.  Additional risks and uncertainties also may materially adversely affect NextEra Energy's or FPL's business, financial condition, future financial results and/or liquidity.

Item 1B.  Unresolved Staff Comments

None

28

Item 2.  Properties

NextEra Energy and its subsidiaries maintain properties which are adequate for their operations.  At December 31, 2010, the electric generating, transmission, distribution and general facilities of FPL represented approximately 47%, 12%, 37% and 4%, respectively, of FPL's gross investment in electric utility plant in service.

Generating Facilities.  At December 31, 2010, NextEra Energy had the following generating facilities:

FPL Facilities	Location	No. of Units	Fuel	Net Capability (mw)(a)
Nuclear
St. Lucie	Hutchinson Island, FL	2	Nuclear		1,553	(b)
Turkey Point	Florida City, FL	2	Nuclear		1,386
Combined-cycle
Fort Myers	Fort Myers, FL	1	Gas		1,432
Lauderdale	Dania, FL	2	Gas/Oil		884
Manatee	Parrish, FL	1	Gas		1,111
Martin	Indiantown, FL	1	Gas/Oil/Solar Thermal		1,105	(c)
Martin	Indiantown, FL	2	Gas		938
Putnam	Palatka, FL	2	Gas/Oil		498
Sanford	Lake Monroe, FL	2	Gas		1,912
Turkey Point	Florida City, FL	1	Gas/Oil		1,148
West County	West Palm Beach, FL	2	Gas/Oil		2,438
Steam turbines
Cutler	Miami, FL	2	Gas		205
Manatee	Parrish, FL	2	Oil/Gas		1,624
Martin	Indiantown, FL	2	Oil/Gas		1,652
Port Everglades	Port Everglades, FL	4	Oil/Gas		1,187
Riviera	Riviera Beach, FL	2	Oil/Gas		565	(d)
St. Johns River Power Park	Jacksonville, FL	2	Coal/Petroleum Coke		254	(e)
Sanford	Lake Monroe, FL	1	Oil/Gas		138
Scherer	Monroe County, GA	1	Coal		646	(f)
Turkey Point	Florida City, FL	2	Oil/Gas		788
Simple-cycle combustion turbines
Fort Myers	Fort Myers, FL	2	Gas/Oil		315
Gas turbines
Fort Myers	Fort Myers, FL	12	Oil		648
Lauderdale	Dania, FL	24	Oil/Gas		840
Port Everglades	Port Everglades, FL	12	Oil/Gas		420
Solar PV
DeSoto	Arcadia, FL	1	Solar PV		25
Space Coast	Cocoa, FL	1	Solar PV		10
TOTAL					23,722	(g)

¾¾¾¾¾¾¾¾¾¾

(a)	Represents FPL's net ownership interest in plant capacity.
(b)	Excludes Orlando Utilities Commission's and the Florida Municipal Power Agency's combined share of approximately 15% of St. Lucie Unit No. 2.
(c)	The megawatts generated by the 75 mw solar thermal facility replace steam produced by this unit and therefore are not incremental.
(d)	In January 2011, these units were removed from service.  See Item 1 - FPL Operations - Fossil Operations for a discussion of plant modernizations.
(e)	Represents FPL's 20% ownership interest in each of SJRPP Units Nos. 1 and 2, which are jointly owned with JEA.
(f)	Represents FPL's approximately 76% ownership of Scherer Unit No. 4, which is jointly owned with JEA.
(g)	Substantially all of FPL's properties are subject to the lien of FPL's mortgage.

29

NextEra Energy Resources Facilities	Location	Geographic Region	No. of Units	Fuel	Net Capability (mw)(a)
Wind
Ashtabula Wind(b)	Barnes County, ND	Midwest	99	Wind	148
Ashtabula Wind II(c)	Griggs & Steele Counties, ND	Midwest	80	Wind	120
Ashtabula Wind III	Barnes County, ND	Midwest	39	Wind	62
Baldwin Wind	Burleigh County, ND	Midwest	64	Wind	102
Butler Ridge Wind(b)	Dodge County, WI	Midwest	36	Wind	54
Cabazon(b)	Riverside County, CA	West	53	Wind	40
Callahan Divide(b)	Taylor County, TX	ERCOT	76	Wind	114
Capricorn Ridge	Sterling & Coke Counties, TX	ERCOT	208	Wind	364
Capricorn Ridge Expansion	Sterling & Coke Counties, TX	ERCOT	199	Wind	298
Cerro Gordo(b)	Cerro Gordo County, IA	Midwest	55	Wind	41
Crystal Lake I(b)(c)	Hancock County, IA	Midwest	100	Wind	150
Crystal Lake II	Winnebago County, IA	Midwest	80	Wind	200
Crystal Lake III	Winnebago County, IA	Midwest	44	Wind	66
Day County Wind(b)	Day County, SD	Midwest	66	Wind	99
Delaware Mountain	Culberson County, TX	ERCOT	38	Wind	28
Diablo Wind(b)	Alameda County, CA	West	31	Wind	21
Elk City Wind(b)	Roger Mills & Beckham Counties, OK	Other South	43	Wind	99
Elk City Wind II	Roger Mills & Beckham Counties, OK	Other South	66	Wind	101
Endeavor Wind	Osceola County, IA	Midwest	40	Wind	100
Endeavor Wind II	Osceola County, IA	Midwest	20	Wind	50
Ghost Pine Wind	Trochu, Alberta, Canada	West	51	Wind	82
Gray County	Gray County, KS	Other South	170	Wind	112
Green Mountain(b)	Somerset County, PA	Northeast	8	Wind	10
Green Power	Riverside County, CA	West	22	Wind	17
Green Ridge Power	Alameda & Contra Costa Counties, CA	West	1,463	Wind	159
Hancock County(b)	Hancock County, IA	Midwest	148	Wind	98
High Winds(b)	Solano County, CA	West	90	Wind	162
Horse Hollow Wind(b)	Taylor County, TX	ERCOT	142	Wind	213
Horse Hollow Wind II(b)	Taylor & Nolan Counties, TX	ERCOT	130	Wind	299
Horse Hollow Wind III(b)	Nolan County, TX	ERCOT	149	Wind	224
Indian Mesa	Pecos County, TX	ERCOT	125	Wind	83
King Mountain(b)	Upton County, TX	ERCOT	214	Wind	278
Lake Benton II(b)	Pipestone County, MN	Midwest	137	Wind	103
Langdon Wind(b)(c)	Cavalier County, ND	Midwest	79	Wind	118
Langdon Wind II(b)(c)	Cavalier County, ND	Midwest	27	Wind	41
Lee / Dekalb Wind	Lee & DeKalb Counties, IL	Midwest	145	Wind	217
Logan Wind(c)	Logan County, CO	West	134	Wind	201
Majestic Wind(b)	Carson County, TX	ERCOT	53	Wind	80
Meyersdale(b)	Somerset County, PA	Northeast	20	Wind	30
Mill Run(b)	Fayette County, PA	Northeast	10	Wind	15
Minco Wind	Grady County, OK	Other South	62	Wind	99
Montezuma Wind	Solano County, CA	West	16	Wind	37
Montfort(b)	Iowa County, WI	Midwest	20	Wind	30
Mount Copper(b)	Murdochville, Quebec, Canada	Midwest	30	Wind	54
Mount Miller(b)	Murdochville, Quebec, Canada	Midwest	30	Wind	54
Mountaineer(b)	Preston & Tucker Counties, WV	Northeast	44	Wind	66
Mower County Wind(c)	Mower County, MN	Midwest	43	Wind	99
New Mexico Wind(b)	Quay & Debaca Counties, NM	West	136	Wind	204
North Dakota Wind(b)	LaMoure County, ND	Midwest	41	Wind	62
Northern Colorado(b)	Logan County, CO	West	81	Wind	174
Oklahoma / Sooner Wind(b)	Harper & Woodward Counties, OK	Other South	68	Wind	102
Oliver County Wind I(c)	Oliver County, ND	Midwest	22	Wind	51
Oliver County Wind II(c)	Oliver County, ND	Midwest	32	Wind	48
Peetz Table Wind(c)	Logan County, CO	West	133	Wind	199
Pubnico Point(b)	Yarmouth, Nova Scotia, Canada	Midwest	17	Wind	31
Red Canyon Wind Energy(b)	Borden, Garza & Scurry Counties, TX	ERCOT	56	Wind	84
Red Mesa Wind	Cibola County, NM	West	64	Wind	102
Sky River(b)	Kern County, CA	West	342	Wind	77
Somerset Wind Power(b)	Somerset County, PA	Northeast	6	Wind	9
South Dakota Wind(b)	Hyde County, SD	Midwest	27	Wind	41
Southwest Mesa(b)	Upton & Crockett Counties, TX	ERCOT	106	Wind	74
Stateline(b)	Umatilla County, OR and Walla Walla County, WA	West	454	Wind	300
Story County Wind(b)	Story County, IA	Midwest	100	Wind	150
Story County Wind II(b)	Story & Hardin Counties, IA	Midwest	100	Wind	150
Vansycle(b)	Umatilla County, OR	West	38	Wind	25
Vansycle II	Umatilla County, OR	West	43	Wind	99
Victory Garden(b)	Kern County, CA	West	96	Wind	22
Waymart(b)	Wayne County, PA	Northeast	43	Wind	65
Weatherford Wind(b)	Custer & Washita Counties, OK	Other South	98	Wind	147

30

NextEra Energy Resources Facilities	Location	Geographic Region	No. of Units	Fuel	Net Capability (mw)(a)
Wessington Springs Wind(b)	Jerauld County, SD	Midwest	34	Wind	51
Wilton Wind(b)	Burleigh County, ND	Midwest	33	Wind	49
Wilton Wind II(c)	Burleigh County, ND	Midwest	33	Wind	50
Windpower Partners 1991-92	Alameda & Contra Costa Counties, CA	West	279	Wind	28
Windpower Partners 1992	Alameda & Contra Costa Counties, CA	West	300	Wind	30
Windpower Partners 1993	Riverside County, CA	West	115	Wind	41
Windpower Partners 1993	Lincoln County, MN	Midwest	73	Wind	26
Windpower Partners 1994	Culberson County, TX	ERCOT	107	Wind	39
Wolf Ridge Wind	Cooke County, TX	ERCOT	75	Wind	112
Woodward Mountain	Upton & Pecos Counties, TX	ERCOT	242	Wind	160
Wyoming Wind(b)	Uinta County, WY	West	80	Wind	144
Investments in joint ventures(d)	Various	West	1,031	Wind	114
Total Wind					8,298
Contracted
Bayswater(b)	Far Rockaway, NY	Northeast	2	Gas	56
Blythe Energy(b)	Blythe, CA	West	3	Gas	507
Calhoun(b)	Eastaboga, AL	Other South	4	Gas/Oil	668
Cherokee(b)	Gaffney, SC	Other South	2	Gas	98
Doswell(b)	Ashland, VA	Northeast	6	Gas/Oil	708
Duane Arnold	Palo, IA	Midwest	1	Nuclear	431	(e)
Jamaica Bay(b)	Far Rockaway, NY	Northeast	2	Gas/Oil	54
Marcus Hook 750(b)	Marcus Hook, PA	Northeast	4	Gas	744
Point Beach	Two Rivers, WI	Midwest	2	Nuclear	1,023
Investments in joint ventures:
SEGS III-IX(b)	Kramer Junction & Harper Lake, CA	West	7	Solar	148
Other	Various	Northeast	7	(f)	303
Total Contracted					4,740
Merchant
Doswell - Expansion(b)	Ashland, VA	Northeast	1	Gas/Oil	171
Forney	Forney, TX	ERCOT	8	Gas	1,792
Lamar Power Partners	Paris, TX	ERCOT	6	Gas	1,000
Maine - Cape, Wyman	Various - ME	Northeast	6	Oil	796	(g)
Maine(b)	Various - ME	Northeast	81	Hydro	359
Marcus Hook 50	Marcus Hook, PA	Northeast	1	Gas	50
Paradise Solar	West Deptford, NJ	Northeast	1	Solar PV	5
RISEP	Johnston, RI	Northeast	3	Gas	550
Seabrook	Seabrook, NH	Northeast	1	Nuclear	1,100	(h)
Investment in joint venture	Frackville, PA	Northeast	1	Waste coal	5
Total Merchant					5,828
TOTAL					18,866

¾¾¾¾¾¾¾¾¾¾

(a)	Represents NextEra Energy Resources' net ownership interest in plant capacity.
(b)	These generating facilities are encumbered by liens against their assets securing various financings.
(c)	NextEra Energy Resources owns these wind facilities together with third-party investors with differential membership interests.  See Note 1 - Sale of Differential Membership Interests.
(d)	Represents plants with no more than 50% ownership using wind technology.  Certain facilities, totaling 57 mw, are encumbered by liens against their assets securing a financing.
(e)	Excludes Central Iowa Power Cooperative and Cornbelt Power Cooperative's combined share of 30%.
(f)	Represents plants with no more than 50% ownership using fuels and technologies such as natural gas and waste coal.
(g)	Excludes six other energy-related partners' combined share of 16%.
(h)	Excludes Massachusetts Municipal Wholesale Electric Company's, Taunton Municipal Lighting Plant's and Hudson Light & Power Department's combined share of 11.77%.

Transmission and Distribution.  At December 31, 2010, FPL owned and operated 587 substations and the following electric transmission and distribution lines:

Nominal Voltage		Overhead Lines Pole Miles			Trench and Submarine Cables Miles
500	kv		1,106	(a)		-
230	kv		3,036			25
138	kv		1,577			53
115	kv		745			1
69	kv		165			14
Less than 69 kv			42,312			25,045
Total			48,941			25,138

¾¾¾¾¾¾¾¾¾¾

(a)  Includes approximately 79 miles owned jointly with JEA.

31

Character of Ownership.  Substantially all of FPL's properties are subject to the lien of FPL's mortgage, which secures most debt securities issued by FPL.  The majority of FPL's real property is held in fee and is free from other encumbrances, subject to minor exceptions which are not of a nature as to substantially impair the usefulness to FPL of such properties.  Some of FPL's electric lines are located on parcels of land which are not owned in fee by FPL but are covered by necessary consents of governmental authorities or rights obtained from owners of private property.  The majority of NextEra Energy Resources' generating facilities are owned by NextEra Energy Resources subsidiaries and a number of those facilities are encumbered by liens securing various financings.  Additionally, the majority of NextEra Energy Resources' generating facilities are located on land leased from owners of private property.  See Generating Facilities and Note 1 - Electric Plant, Depreciation and Amortization.

Item 3.  Legal Proceedings

NextEra Energy 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 NextEra Energy or FPL, see Note 14 - Legal Proceedings.  Such descriptions are incorporated herein by reference.

PART II

Item 5.  Market for Registrants' Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Common Stock Data.  All of FPL's common stock is owned by NextEra Energy.  NextEra Energy's common stock is traded on the New York Stock Exchange under the symbol "NEE."  The high and low sales prices for the common stock of NextEra Energy as reported in the consolidated transaction reporting system of the New York Stock Exchange and the cash dividends per share declared for each quarter during the past two years are as follows:

	2010						2009
Quarter	High		Low		Cash Dividends		High		Low		Cash Dividends
First	$	53.75	$	45.29	$	0.50	$	53.99	$	41.48	$	0.4725
Second	$	53.50	$	47.96	$	0.50	$	59.00	$	49.70	$	0.4725
Third	$	55.98	$	48.44	$	0.50	$	60.61	$	53.13	$	0.4725
Fourth	$	56.26	$	50.00	$	0.50	$	56.57	$	48.55	$	0.4725

The amount and timing of dividends payable on NextEra Energy's common stock are within the sole discretion of NextEra Energy's Board of Directors.  The Board of Directors reviews the dividend rate at least annually (generally in February) to determine its appropriateness in light of NextEra Energy's financial position and results of operations, legislative and regulatory developments affecting the electric utility industry in general and FPL in particular, competitive conditions and any other factors the Board of Directors deems relevant.  The ability of NextEra Energy to pay dividends on its common stock is dependent upon, among other things, dividends paid to it by its subsidiaries.  There are no restrictions in effect that currently limit FPL's ability to pay dividends to NextEra Energy.  In February 2011, NextEra Energy announced that it would increase its quarterly dividend on its common stock from $0.50 to $0.55 per share.  See Management's Discussion - Liquidity and Capital Resources - Covenants with respect to dividend restrictions and Note 11 - Common Stock Dividend Restrictions regarding dividends paid by FPL to NextEra Energy.

As of the close of business on January 31, 2011, there were 26,577 holders of record of NextEra Energy's common stock.

Issuer Purchases of Equity Securities.Information regarding purchases made by NextEra Energy of its common stock 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)
10/1/10 - 10/31/10		322		$	55.51		-	20,000,000
11/1/10 - 11/30/10		12,250		$	53.57		-	20,000,000
12/1/10 - 12/31/10		2,552		$	51.93		-	20,000,000
Total		15,124		$	53.33		-

¾¾¾¾¾¾¾¾¾¾

(a)

Includes:  (1) in each of October 2010, November 2010 and December 2010, 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 Long-Term Incentive Plan (LTIP); and (2) in December 2010, shares of common stock purchased as a reinvestment of dividends by the trustee of a grantor trust in connection with NextEra Energy's obligation under a February 2006 grant under the LTIP of deferred retirement share awards to an executive officer.

(b)

In February 2005, NextEra Energy's Board of Directors authorized a common stock repurchase plan of up to 20 million shares of common stock over an unspecified period, which authorization was ratified and confirmed by the Board of Directors in December 2005.

32

Item 6.  Selected Financial Data

	Years Ended December 31,
	2010			2009			2008			2007			2006
SELECTED DATA OF NEXTERA ENERGY (millions, except per share amounts):
Operating revenues	$	15,317		$	15,643		$	16,410		$	15,263		$	15,710
Net income	$	1,957	(a)	$	1,615	(a)	$	1,639	(a)	$	1,312	(a)	$	1,281	(b)
Earnings per share of common stock - basic	$	4.77	(a)	$	3.99	(a)	$	4.10	(a)	$	3.30	(a)	$	3.25	(b)
Earnings per share of common stock - assuming dilution	$	4.74	(a)	$	3.97	(a)	$	4.07	(a)	$	3.27	(a)	$	3.23	(b)
Dividends paid per share of common stock	$	2.00		$	1.89		$	1.78		$	1.64		$	1.50
Total assets	$	52,994		$	48,458		$	44,821		$	40,123		$	35,822
Long-term debt, excluding current maturities	$	18,013		$	16,300		$	13,833		$	11,280		$	9,591
SELECTED DATA OF FPL (millions):
Operating revenues	$	10,485		$	11,491		$	11,649		$	11,622		$	11,988
Net income	$	945		$	831		$	789		$	836		$	802
Total assets	$	28,698		$	26,812		$	26,175		$	24,044		$	22,970
Long-term debt, excluding current maturities	$	6,682		$	5,794		$	5,311		$	4,976		$	4,214
Energy sales (kwh)		107,978			105,414			105,406			108,636			107,513
Energy sales:
Residential		52.2	%		51.2	%		50.5	%		50.8	%		50.8	%
Commercial		41.3			42.7			43.2			42.3			41.4
Industrial		2.9			3.1			3.4			3.5			3.8
Interchange power sales		0.8			1.4			1.6			1.8			2.1
Other(c)		2.8			1.6			1.3			1.6			1.9
Total		100.0	%		100.0	%		100.0	%		100.0	%		100.0	%
Approximate 60-minute peak load (mw):(d)
Summer season		22,256			22,351			21,060			21,962			21,819
Winter season		21,153			24,346			20,031			18,055			17,260
Average number of customer accounts (thousands):
Residential		4,004			3,984			3,992			3,981			3,906
Commercial		504			501			501			493			479
Industrial		9			10			13			19			21
Other		3			4			4			4			4
Total		4,520			4,499			4,510			4,497			4,410
Average price billed to customers (cents per kwh)		9.34			11.19			10.96			10.63			11.14

¾¾¾¾¾¾¾¾¾¾

(a)	Includes net unrealized mark-to-market gains or losses associated with non-qualifying hedges and other than temporary impairment losses.
(b)	Includes expenses related to a terminated merger, net unrealized mark-to-market gains associated with non-qualifying hedges, impairment charges and an Indonesian project gain.
(c)	Includes the net change in unbilled sales.
(d)	Winter season includes November and December of the current year and January to March of the following year (for 2010, through February 24, 2011).

33

Item 7.  Management's Discussion and Analysis of Financial Condition and Results of Operations

This discussion should be read in conjunction with the Notes to Consolidated Financial Statements contained herein.  In the discussion of Results of Operations below, all comparisons are with the corresponding items in the prior year.

Overview

NextEra Energy is one of the nation's largest providers of electricity-related services.  It has two principal operating subsidiaries, FPL and NextEra Energy Resources.  FPL, a rate-regulated utility, serves more than 8.7 million people throughout most of the east and lower west coasts of Florida.  NextEra Energy Resources, NextEra Energy's competitive energy subsidiary, produces electricity primarily using wind, natural gas and nuclear resources.  Together, FPL's and NextEra Energy Resources' generating assets represented approximately 42,600 mw of capacity at December 31, 2010.  See Item 2 - Generating Facilities.  Corporate and Other, discussed below, includes FPL FiberNet, which provides fiber-optic services to FPL, telecommunications companies and other custome rs throughout Florida, and Lone Star, a rate-regulated utility in Texas.

FPL obtains its operating revenues primarily from the sale of electricity to retail customers at rates established by the FPSC through base rates and cost recovery clause mechanisms.  Effective March 1, 2010, pursuant to the FPSC rate order, new retail base rates for FPL were established, resulting in an increase in retail base revenues of approximately $75 million on an annualized basis.  The FPSC rate order also established a regulatory ROE of 10.0% with a range of plus or minus 100 basis points and an adjusted regulatory equity ratio of 59.1%, and shifted certain costs from retail base rates to the capacity clause.  In addition, the FPSC rate order directed FPL to reduce depreciation expense (surplus depreciation credit) over the 2010 to 2013 period related to a depreciation reserve surplus of app roximately $895 million.  Subsequently, the principal parties in FPL’s 2009 rate case signed the 2010 rate agreement and, on February 1, 2011, the FPSC issued a final order reflecting its decision to approve the 2010 rate agreement.  Key elements of the 2010 rate agreement, which will be effective through December 31, 2012, are as follows:

· Subject to the provisions of the 2010 rate agreement, retail base rates will be effectively frozen through the end of 2012.

· Incremental cost recovery through FPL’s capacity clause for WCEC Unit No. 3, which is expected to be placed in service by mid-2011, will be permitted up to the amount of the projected fuel savings for customers during the term of the 2010 rate agreement.  See Item 1 - FPL Operations - Fossil Operations.

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

· If FPL's earned regulatory ROE falls below 9%, FPL may seek retail base rate relief.  If FPL's earned regulatory ROE rises above 11%, any party to the 2010 rate agreement may seek a reduction in FPL’s retail base rates.  In determining the regulatory ROE for all purposes under the 2010 rate agreement, earnings will be calculated on an actual, non-weather-adjusted basis.

· FPL can vary the amount of surplus depreciation credit taken in any calendar year up to a cap in 2010 of $267 million, a cap in subsequent years of $267 million plus the amount of any unused portion from prior years, and a cap of $776 million (surplus depreciation credit cap) over the course of the 2010 rate agreement, provided that in any year of the 2010 rate agreement, including 2010, FPL must use at least enough surplus depreciation credit to maintain a 9% earned regulatory ROE but may not use any amount of surplus depreciation credit that would result in an earned regulatory ROE in excess of 11%.  As of December 31, 2010, approximately $772 million of the surplus depreciation credit cap remains.

NextEra Energy's and FPL's financial statements in Item 8 reflect the effects of the FPSC rate order and the 2010 rate agreement.

Under the terms of the 2005 rate agreement, which was in effect from January 1, 2006 through February 28, 2010, retail base rates did not increase except to allow recovery of the revenue requirements of FPL’s three power plants that achieved commercial operation during the term of the 2005 rate agreement:  Turkey Point Unit No. 5 in 2007 and WCEC Units Nos. 1 and 2 in 2009.  Under the terms of the 2005 rate agreement, FPL's electric property depreciation rates were based upon the comprehensive depreciation studies it filed with the FPSC in March 2005; however, FPL reduced depreciation on its plant in service by $125 million each year as allowed by the 2005 rate agreement.  The 2005 rate agreement also provided for a revenue sharing mechanism, whereby revenues from retail base ope rations in excess of certain thresholds would be shared with customers.  During the term of the 2005 rate agreement, FPL's revenues did not exceed the thresholds.

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In 2010, FPL's retail customer growth was 0.5%, compared to a 0.2% decline in customers in 2009 and a 0.3% increase in 2008.  Positive customer growth is projected to continue in 2011, although the rate of growth is projected to be below FPL’s average rate of 1.6% over the last 10 years.  Non-weather related usage per retail customer began to decline in the mid-2000s and this decline intensified in the 2007 to 2009 period.  The rate of decline in non-weather related usage per retail customer moderated in 2010.  Inactive accounts (accounts with installed meters without corresponding customer names) and low-usage customers (customers using less than 200 kwh per month) began to increase in 2007 and peaked in 2009.  At December 31, 2010, inactive accounts were approximately 6.0% less than they had been at December 31, 2009 while the number of low-usage customers was 2.5% higher than they were at December 31, 2009.  FPL believes that the economic slowdown and the downturn in the housing market that have affected the country and the state of Florida have contributed to the slowdown in customer growth and to the decline in non-weather related usage per retail customer.  A portion of the decline in non-weather related usage per retail customer may also be related to federal and state mandated energy efficiency measures.  The unemployment rate in Florida was 12.0% and 11.7% in December 2010 and 2009, respectively, and was as high as 12.3% in early 2010.  FPL is unable to predict whether or when growth in customers and non-weather related customer usage might return to previous trends.

NextEra Energy Resources is in the competitive energy business with the majority of its operating revenues derived from wholesale electricity sales.  NextEra Energy Resources' strategy is, among other things, to continue to maintain its leadership position in wind, accelerate growth in solar development, continue to expand its transmission capability, grow its customer supply and proprietary power and gas trading businesses, and develop its natural gas infrastructure business.  NextEra Energy Resources' customer supply business includes full energy and capacity requirements services and the operations of a retail electricity provider.  NextEra Energy Resources seeks to expand its generation portfolio primarily through wind and solar development and acquisitions where economic prospects are attractive. 0; NextEra Energy Resources plans to add approximately 3,500 mw to 5,000 mw of new wind generation in 2010 to 2014, including 754 mw added in 2010 and approximately 700 mw to 1,000 mw in 2011.  In addition to wind expansion, NextEra Energy Resources is considering several solar development opportunities in the United States and Europe, and plans to add approximately 400 mw to 600 mw of new solar generation in 2010 through 2014, including 5 mw added in 2010.  The wind and solar expansions are subject to, among other things, continued public policy support, support for the construction and availability of sufficient transmission facilities and capacity, continued market demand, supply chain expansion and access to capital at reasonable cost and on reasonable terms.  NextEra Energy Resources continues to invest in natural gas infrastructure opportunities.  NextEra Energy Resources is evaluating additional natural gas infrastructure opportunities and will continue to explore additional projects as opportunities that it believes will be economically attractive become available.

NextEra Energy Resources' market is diversified by region as well as by fuel source.  See Item 2 - Generating Facilities.  NextEra Energy Resources sells a large percentage of its expected output to hedge against price volatility.  Consequently, if NextEra Energy Resources' plants do not perform as expected, NextEra Energy Resources could be required to purchase power at potentially higher market prices to meet its contractual obligations.  NextEra Energy Resources' energy marketing and trading business is focused primarily on managing commodity price risk and extracting maximum value from its assets.

The U.S. Congress, the EPA and certain states and regions continue to consider several legislative and regulatory proposals with respect to GHG emissions.  The economic and operational impact of any legislation and/or regulation on NextEra Energy and FPL depends on a variety of factors, including, but not limited to, the allowed emissions, whether emission allowances will be allocated or auctioned, the cost to reduce emissions or buy allowances in the marketplace and the availability of offsets and mitigating factors to moderate the costs of compliance.  If and until legislation is enacted and implementing regulations are adopted, the economic and operational impact (either positive or negative) on NextEra Energy and FPL cannot be determined, but could be material.  In the case of FPL, increased costs ass ociated with compliance with new environmental regulations are generally recoverable from customers, while the recovery of such increased costs for NextEra Energy Resources would depend on market prices for electricity.  See Item 1 - Environmental Matters.

Results of Operations

NextEra Energy and NextEra Energy Resources 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 trading activities, represents the net unrealized effect of actively traded positions entered into to take advantage of market price movements and to optimize the value of generation assets and related contracts.  The second category, referred to as non-qualifying hedges, represents the net unrealized effect of derivative and certain other transactions entered into as economic hedges but which do not qualify for hedge accounting, or hedge accounting was not elected, and the ineffective portion of transactions accounted for as cash flow hedges.  In January 2010, NextEra Energy discontinued hedge accounting for its cash flow hedges related to energy contract derivative instruments, which could result in increased volatility in the non-qualifying hedge category.  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 3.

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NextEra Energy's management uses earnings excluding certain items (adjusted earnings) 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 NextEra Energy's employee incentive compensation plans.  NextEra Energy also uses adjusted earnings when communicating its financial results and earnings outlook to investors.  Adjusted earnings exclude the unrealized mark-to-market effect of non-qualifying hedges and other than temporary impairment (OTTI) losses on securities held in NextEra Energy Resources' 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).  NextEra Energy's management believes adjusted earnings provide 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 generally accepted accounting principles, 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 generally accepted accounting principles.

Summary - Presented below is a summary of net income by reportable segment (see Note 15).  Beginning in 2010, NextEra Energy Resources' results reflect an allocation of interest expense from Capital Holdings to NextEra Energy Resources based on a deemed capital structure of 70% debt and allocated shared service costs.  NextEra Energy's other reportable segment, FPL, a rate-regulated utility, was not affected by these changes.  Prior year segment data of NextEra Energy Resources and Corporate and Other has been restated to include the effect of these changes.  Corporate and Other represents other business activities, other segments that are not separately reportable and eliminating entries.

	Years Ended December 31,
	2010		2009		2008
			(millions)
FPL	$	945	$	831	$	789
NextEra Energy Resources		980		759		831
Corporate and Other		32		25		19
NextEra Energy Consolidated	$	1,957	$	1,615	$	1,639

The increase in FPL's 2010 results reflects higher retail customer usage of 1.7%, retail base rate increases resulting from the placement in service of WCEC Units Nos. 1 and 2 in 2009, the impact of the FPSC rate order and higher cost recovery clause results, partly offset by higher depreciation and amortization expense recovered through base rates, higher O&M, property tax and interest expenses and lower AFUDC - equity.  The increase compared to the prior year period in retail customer usage reflects colder weather in the first quarter and warmer weather in the second and third quarters, and other factors, partly offset by lower usage in the fourth quarter.  FPL's 2009 results reflects retail base rate increases resulting from the placement in service of WCEC Units Nos. 1 and 2, higher AFUDC - equity on the WCEC units, a 0.3% increase in usage per retail customer reflecting favorable weather conditions partly offset by other factors, and higher cost recovery clause results partly offset by higher O&M and depreciation and amortization expenses recovered through base rates.

NextEra Energy Resources’ results for 2010 and 2009 were affected by net unrealized after-tax gains and losses from non-qualifying hedges, after-tax OTTI losses on securities held in its nuclear decommissioning funds and after-tax OTTI reversals.  See table below for details of such gains, losses and reversals, all of which are included in NextEra Energy's and NextEra Energy Resources’ net income.

	Years Ended December 31,
	2010			2009			2008
				(millions)
Net unrealized mark-to-market after-tax gains (losses) from non-qualifying hedge activity	$	176		$	(20	)	$	170
OTTI after-tax losses on securities held in nuclear decommissioning funds	$	(9	)	$	(36	)	$	(82	)
OTTI after-tax reversals	$	13		$	23		$	6

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 generally accepted accounting principles.

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NextEra Energy Resources’ results for 2010 also reflect higher earnings from the existing asset portfolio, earnings from new investments and higher gas infrastructure results.  These results were partially offset by lower results from the customer supply and proprietary power and gas trading businesses, the absence of a tax benefit recorded in 2009 reflecting the reduction of previously deferred income taxes resulting from an additional equity investment in Canadian operations (foreign tax benefit), the absence of a tax benefit recorded in 2009 related to a change in state tax law that extended the carry forward period of ITCs on certain wind projects (state tax benefit), a writedown of the value of certain assets associated with plans to repower two California wind facilities and higher expenses to support the growth of the business.  NextEra Energy Resources’ 2009 results also reflect increased earnings from new investments and the customer supply and proprietary power and gas trading businesses, partly offset by lower earnings from the existing asset portfolio, reflecting the negative impacts of weather and higher expenses to support the growth in the business.  See footnote (a) to the table under NextEra Energy Resources below for a description of projects included in new investments and the existing asset portfolio.

Results for Corporate and Other in 2010 reflect higher consolidating income tax benefits, including a one-time benefit of $24 million related to deferred income taxes, and higher interest income, partly offset by higher interest expense.  Results for Corporate and Other in 2009 reflect higher interest income and realized and unrealized gains on investments, partly offset by lower consolidating income tax adjustments and higher interest expense.

NextEra Energy's effective income tax rate for all periods presented reflects PTCs for wind projects at NextEra Energy Resources and, for 2010 and 2009, deferred tax benefits associated with grants (convertible ITCs) under the Recovery Act.  PTCs and deferred tax benefits associated with convertible ITCs can significantly affect NextEra Energy's effective income tax rate depending on the amount of pretax income.  PTCs can be significantly affected by wind generation.  See Note 1 - Income Taxes and - Sale of Differential Membership Interests and Note 6.

FPL - FPL's net income for 2010, 2009 and 2008 was $945 million, $831 million and $789 million, respectively, an increase in 2010 of $114 million and an increase in 2009 of $42 million.  See Summary above for a discussion of the major drivers of these increases.  See Overview for a discussion of FPSC rate matters.

FPL's operating revenues consisted of the following:

	Years Ended December 31,
	2010		2009			2008
			(millions)
Retail base	$	4,190	$	3,828		$	3,738
Fuel cost recovery		4,090		5,982			6,202
Net repayment of previously deferred retail fuel revenues		356		-			-
Net deferral of retail fuel revenues		-		(356	)		-
Other cost recovery clauses and pass-through costs, net of any deferrals		1,638		1,840			1,505
Other, primarily pole attachment rentals, transmission and wholesale sales and customer-related fees		211		197			204
Total	$	10,485	$	11,491		$	11,649

For the year ended December 31, 2010, a 0.5% increase in the average number of customer accounts increased retail base revenues by approximately $19 million, while a 1.7% increase in usage per retail customer, reflecting cold weather experienced in the first quarter and warmer weather in the second and third quarters and other factors partly offset by lower usage in the fourth quarter, increased retail base revenues by approximately $79 million.  Base rate increases resulting from two WCEC units commencing commercial operation in August and November 2009 and the base rate increase pursuant to the FPSC rate order increased retail base revenues for the year ended December 31, 2010 by approximately $196 million and $68 million, respectively.  See Overview for a discussion of FPL's customer growth and non-wea ther related usage.

For the year ended December 31, 2009, a 0.2% decrease in the average number of customer accounts reduced retail base revenues by approximately $8 million while a 0.3% increase in usage per retail customer, reflecting favorable weather conditions partly offset by other factors, increased retail base revenues by approximately $30 million.  Customer usage in 2009 reflects one less day of sales in 2009, as 2008 was a leap year.  Base rate increases resulting from the two WCEC units commencing commercial operation in 2009 increased retail base revenues by approximately $68 million.

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Revenues from fuel and other cost recovery clauses and pass-through costs, such as franchise fees, revenue taxes and storm-related surcharges, are largely a pass-through of costs.  Such revenues also include a return allowed to be recovered through the cost recovery clauses on certain assets, primarily related to solar, environmental and nuclear capacity projects.  In 2010, 2009 and 2008, cost recovery clauses contributed $75 million, $41 million and $25 million, respectively, to FPL's net income.  The increase in 2010 and 2009 cost recovery clause results is primarily due to a return related to additional solar, environmental and nuclear capacity expenditures, partly offset in 2009 by lower interest earned on fuel clause underrecoveries.  In 2011, it is expected that cost recovery clauses will contribute higher earnings for FPL as a result of additional nuclear capacity and environmental expenditures.  Underrecovery or overrecovery of such cost recovery clause and pass-through costs can significantly affect NextEra Energy's and FPL's operating cash flows.  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 consolidated statements of income, as well as by changes in energy sales.  Fluctuations in revenues from other cost recovery clauses and pass-through costs are primarily driven by changes in storm-related surcharges, capacity charges, franchise fee costs, the impact of changes in O&M and depreciation expenses on the underlying cost recovery clause, investment in solar and environmental projects, investment in nuclear capacity until such capacity goes into service, pre-construction costs associated with the development of two additional n uclear 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 consolidated statements of income.

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 amounted to approximately $236 million and $68 million at December 31, 2010 and 2009, respectively.  Pursuant to an FPSC order, FPL was required to refund in the form of a one-time credit to retail customers' bills the 2009 year-end estimated fuel overrecovery; during the first quarter of 2010, approximately $404 million was refunded to re tail customers.  At December 31, 2009, approximately $356 million of retail fuel revenues were overrecovered, the reversal of which is reflected in the net repayment of previously deferred retail fuel revenues caption included in the table above.  The difference between the refund and the December 31, 2009 overrecovery will be collected from retail customers after 2010.  The decrease in fuel revenues in 2010 reflects the $404 million refund and approximately $1,573 million related to a lower average fuel factor, partly offset by $85 million attributable to higher energy sales.  The decrease in fuel revenues in 2009 reflects approximately $210 million related to a lower average fuel factor and $10 million attributable to lower energy sales.  The decrease from December 31, 2009 to December 31, 2010 in deferred clause and franchise revenues and the increase in deferred clause and franchise expenses (current and noncurrent, collectively) on Ne xtEra Energy's and FPL's consolidated balance sheets totaled approximately $629 million and negatively affected NextEra Energy's and FPL's cash flows from operating activities for the year ended December 31, 2010.

The decrease in revenues from other cost recovery clauses and pass-through costs in 2010 is primarily due to lower revenues associated with the FPSC's nuclear cost recovery rule and lower revenues related to franchise and revenue taxes, partly offset by higher environmental clause revenues.  The increase in revenues from other cost recovery clauses and pass-through costs in 2009 is primarily due to additional revenues associated with the FPSC's nuclear cost recovery rule and higher conservation and environmental clause revenues.  The FPSC's nuclear cost recovery rule provides for the recovery of prudently incurred pre-construction costs and carrying charges (equal to a pretax AFUDC rate) on construction costs for new nuclear capacity through levelized charges under the capacity clause.  In 2009, FPL began recovering pre-construction costs associated with the development of two additional nuclear units at the Turkey Point site and carrying charges (equal to a pretax AFUDC rate) on construction costs associated with the addition of approximately 400 mw to 460 mw of capacity at its existing nuclear units.  The same rule provides for the recovery of construction costs, once property related to the new nuclear capacity goes into service, through a base rate increase.  The decline in 2010 in revenues associated with the nuclear cost recovery rule is primarily due to lower spending related to the development of the two additional nuclear units at the Turkey Point site.  The decline in 2010 revenues related to franchise and revenue taxes reflects the decline in fuel revenues.

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

	Years Ended December 31,
	2010			2009		2008
				(millions)
Fuel and energy charges during the period	$	4,714		$	5,425	$	6,289
Net collection of previously deferred retail fuel costs		-			256		-
Net deferral of retail fuel costs		(276	)		-		(55	)
Other, primarily capacity charges, net of any capacity deferral		544			539		515
Total	$	4,982		$	6,220	$	6,749

The decrease in fuel and energy charges in 2010 reflects lower fuel and energy prices of approximately $822 million, partly offset by approximately $111 million attributable to higher energy sales.  The decrease in fuel and energy charges in 2009 was due to lower fuel and energy prices.

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FPL's O&M expenses increased $124 million in 2010 reflecting an approximately $20 million charge for workforce reductions and higher nuclear and fossil generation, distribution, transmission and nuclear insurance costs of approximately $34 million, $29 million, $16 million, $8 million and $12 million, respectively, partly offset by lower customer service costs, primarily due to lower uncollectible accounts, of $13 million.  The increase in nuclear generation costs is primarily due to higher maintenance costs and reflects a reimbursement in 2009 of prior years’ costs of approximately $10 million related to a spent nuclear fuel litigation settlement agreement with the U.S. Government.  The increase in fossil generation costs is primarily related to WCEC Units Nos. 1 and 2, which units were placed in se rvice in the second half of 2009, and higher plant overhaul costs.  The increase in distribution and transmission costs reflects higher restoration and tree trimming costs.  Other changes in O&M expenses were primarily driven by pass-through costs which did not significantly affect net income.

FPL's O&M expenses increased $58 million in 2009 reflecting higher insurance and employee benefit costs of approximately $51 million and $44 million, respectively, partly offset by lower distribution, nuclear and fossil generation costs of $26 million, $18 million and $10 million, respectively.  The increase in insurance costs is primarily due to the absence of a refund associated with an environmental insurance policy termination, which occurred in 2008, as well as higher nuclear insurance costs.  The increase in employee benefit costs is primarily due to higher medical costs, a lower pension credit and other costs driven by market conditions.  The decrease in distribution costs reflects deferred projects and productivity improvements.  The decline in nuclear generation costs reflects a rei mbursement of prior years’ costs related to the spent fuel settlement agreement and lower costs related to 2008 plant improvement initiatives partly offset by higher refueling and maintenance outage costs.  The decline in fossil generation costs is primarily due to lower overhaul costs, partly offset by additional costs related to WCEC Units Nos. 1 and 2.  Other changes in O&M expenses were primarily driven by pass-through costs which did not significantly affect net income.

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

	Years Ended December 31,
	2010			2009			2008
				(millions)
$125 million annual reduction under the 2005 rate agreement	$	-		$	(125	)	$	(125	)
Surplus depreciation credit recorded under the 2010 rate agreement		(4	)		-			-
Other depreciation and amortization recovered under base rates		891			942			908
Depreciation and amortization recovered under cost recovery clauses		121			280			77
Total	$	1,008		$	1,097		$	860

FPL had been recording the $125 million annual reduction in depreciation and amortization expense since 2002, as approved by the FPSC in previous rate orders.  See Overview regarding the amount of surplus depreciation credit that FPL may record over the term of the 2010 rate agreement.  The decline in other depreciation and amortization expense recovered under base rates in 2010 is primarily due to lower depreciation rates as a result of the FPSC rate order, partly offset by higher plant in service balances related to WCEC Units Nos. 1 and 2, which were placed in service in August and November 2009, respectively.  The increase in depreciation and amortization expense recovered under base rates in 2009 is primarily due to higher depreciation on transmission and distribution facilities, as well as WCEC Units Nos. 1 and 2.  Depreciation and amortization recorded under cost recovery clauses in 2010 and 2009 reflects changes in the amortization of pre-construction costs associated with FPL's planned nuclear units recovered under the nuclear cost recovery rule.  See Note 1 - Electric Plant, Depreciation and Amortization.

Taxes other than income taxes and other decreased $71 million in 2010 and increased $24 million in 2009 primarily due to changes in franchise fees and revenue taxes, which are pass-through costs.  In addition, taxes other than income taxes and other in 2010 and 2009 reflect higher property taxes of $34 million and $14 million, respectively, due to growth in plant in service balances and, for 2010, a higher property tax rate.

The increase in interest expense in 2010 is primarily due to higher average debt balances, as well as lower AFUDC - debt.  The decrease in interest expense in 2009 reflects a decline in average interest rates of approximately 29 basis points and higher AFUDC - debt, partly offset by higher average debt balances.  See AFUDC - equity below for explanation of the change in AFUDC - debt.  Interest expense on storm-recovery bonds, as well as certain other interest expense (collectively, clause interest), are essentially pass-through amounts and do not significantly affect net income, as the clause interest is recovered either under cost recovery clause mechanisms or through a storm-recovery bond surcharge.  Clause interest for 2010, 2009 and 2008 amounted to approximately $56 million, $45 millio n and $44 million, respectively.  The increase in clause interest in 2010 is primarily due to higher interest associated with solar, environmental and nuclear capacity expenditures.

The decrease in AFUDC - equity in 2010 is primarily attributable to WCEC Units Nos. 1 and 2, which units commenced commercial operation in 2009, partly offset by additional AFUDC - equity on WCEC Unit No. 3.  The decrease in AFUDC - equity also reflects a decline, effective April 1, 2010, in the AFUDC rate from 7.41% to 6.41%, as approved by the FPSC.  The increase in AFUDC - equity in 2009 is primarily attributable to additional AFUDC - equity on WCEC Unit Nos. 1, 2 and 3.

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FPL currently faces competition from other suppliers of electrical energy to wholesale customers and from alternative energy sources and self-generation for other customer groups, primarily industrial customers.  The FERC has jurisdiction over potential changes that could affect competition in wholesale transactions.  In 2010, operating revenues from wholesale and industrial customers combined represented approximately 3% of FPL's total operating revenues.  Various states, other than Florida, have enacted legislation or have state commissions that have issued orders designed to allow retail customers to choose their electricity supplier.  Management believes it is unlikely there will be any state actions to restructure the retail electric industry in Florida in the near future.  If the basis of regulation for some or all of FPL's business changes from cost-based regulation, existing regulatory assets and liabilities would be written off unless regulators specify an alternative means of recovery or refund.  Further, other aspects of the business, such as generation assets and long-term power purchase commitments, would need to be reviewed to assess their recoverability in a changed regulatory environment.  See Critical Accounting Policies and Estimates - Regulatory Accounting.

FPL is currently constructing WCEC Unit No. 3, a natural gas-fired combined-cycle unit of approximately 1,220 mw, which is expected to be placed in service by mid-2011.  In addition, FPL is in the process of adding approximately 400 mw to 460 mw of capacity at its existing nuclear units at St. Lucie and Turkey Point, which additional capacity is projected to be placed in service from spring 2011 to 2013.  FPL is also in the process of modernizing its Cape Canaveral and Riviera Beach power plants to high-efficiency natural gas-fired units and expects the units to be placed in service by 2013 and 2014, respectively.  Each modernized plant is expected to provide approximately 1,200 mw of capacity.  A 10 mw solar PV facility in Brevard County, Florida was placed in service in April 2010 and a 75 mw solar thermal facility in Martin County, Florida was placed in service in December 2010.

NextEra Energy Resources - NextEra Energy Resources’ 2009 and 2008 segment results have been restated to reflect a change in the method of allocating non-utility interest expense and the allocation of shared service costs.  See Summary above and Note 15 for additional discussion.  NextEra Energy Resources’ net income for 2010, 2009 and 2008 was $980 million, $759 million and $831 million, respectively, an increase in 2010 of $221 million and a decrease in 2009 of $72 million.  The primary drivers, on an after-tax basis, of these changes were as follows:

	Increase (Decrease) From Prior Period
	Years Ended December 31,
	2010			2009
	(millions)
New investments(a)	$	45		$	173
Existing assets(a)		54			(213	)
Gas infrastructure		23			3
Customer supply and proprietary power and gas trading businesses		(25	)		120
Asset sales		7			6
Interest expense, differential membership costs and other		(96	)		(34	)
Change in unrealized mark-to-market non-qualifying hedge activity(b)(c)		196			(190	)
Change in OTTI losses on securities held in nuclear decommissioning funds, net of OTTI reversals(c)		17			63
Net income increase (decrease)	$	221		$	(72	)

¾¾¾¾¾¾¾¾¾¾

(a)	Includes PTCs and ITCs on wind projects and ITCs on solar projects and, for new investments, deferred tax benefits associated with convertible ITCs (see Note 1 - Electric Plant, Depreciation and Amortization, Note 1 - Income Taxes and Note 6) 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)	See Note 3 and discussion above related to derivative instruments.
(c)	See table in Summary above for additional detail.

The increase in NextEra Energy Resources’ 2010 results from new investments reflects the addition of over 2,100 mw of wind generation during or after 2009 and a benefit related to state ITCs.  The increase in NextEra Energy Resources’ 2009 results from new investments reflects the addition of over 2,490 mw of wind generation during or after 2008.  Results from new investments for the years ended December 31, 2010 and 2009 include approximately $66 million and $87 million, respectively, of deferred tax benefits associated with convertible ITCs.

In 2010, results from NextEra Energy Resources' existing asset portfolio increased primarily due to favorable results at Seabrook of approximately $62 million resulting primarily from the absence of an extended outage in 2010.  In addition, 2010 results from the existing asset portfolio reflects favorable generation due to lower curtailments and a higher wind resource across the wind portfolio totaling approximately $46 million.  These results were partially offset by unfavorable market conditions in the ERCOT market affecting NextEra Energy Resources' merchant gas assets totaling approximately $30 million and the absence of the state tax benefit of $15 million.  In 2009, results from NextEra Energy Resources' existing asset portfolio decreased approximately $110 million primarily due to unfavorable resul ts in the ERCOT and NEPOOL markets due primarily to unfavorable market conditions, lower results of $75 million associated with existing wind projects primarily due to a lower wind resource across the portfolio and lower results of $36 million from the contracted portfolio, partly offset by the state tax benefit and favorable results at Seabrook primarily due to higher prices.  The increase in gas infrastructure results in 2010 is primarily due to exiting the hedged positions on a small number of future drilling opportunities.

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Results from the customer supply and proprietary power and gas trading businesses decreased in 2010 primarily due to lower power and gas trading results, partly offset by a gain from the sale of a power supply contract that NextEra Energy Resources entered into in 2009.  The increase in 2009 is due to higher power and gas trading results and favorable residential sales margins from the retail electricity provider.

Asset sales in 2010 include an after-tax gain of approximately $6 million on the sale of a coal-fired project and an after-tax gain on a waste-to-energy project of approximately $12 million recorded in 2010 after the expiration of an option for the buyer to sell the project back to NextEra Energy Resources.  Asset sales in 2009 include after-tax gains of $3 million for the sale of wind development rights, $6 million for the sale of a 50 mw wind project and $2 million for the sale of an interest in the waste-to-energy project while asset sales in 2008 reflect a $6 million after-tax gain on the sale of development rights on a natural gas project.

In both 2010 and 2009, interest expense, differential membership costs and other reflects higher interest and other costs due to growth of the business and, for 2010, also reflects an after-tax writedown of approximately $11 million in the value of certain assets associated with the plans to repower two California wind facilities and the absence of the foreign tax benefit of $18 million which was recorded in 2009.  In 2009, the foreign tax benefit was offset by other income tax expenses in 2009 and the absence of other income tax benefits recorded in the prior year.

Operating revenues for the year ended December 31, 2010 increased $639 million primarily due to higher revenues at PMI and NextEra Energy Resources' retail electricity provider (collectively, approximately $242 million), project additions ($143 million), higher gas infrastructure revenues of $31 million, higher revenues in the existing asset portfolio of $206 million primarily due to the absence of an extended outage in 2010 at Seabrook, favorable generation due to lower curtailments and a higher wind resource across the wind portfolio.  In addition, operating revenues increased due to losses of $75 million on unrealized mark-to-market non-qualifying hedge activity compared to $88 million of such losses in 2009.  Operating revenues for the year ended December 31, 2009 decreased $573 million primarily due to losses of $88 million on unrealized mark-to-market non-qualifying hedge activity in 2009 compared to gains on such hedges of $232 million in 2008.  Excluding this mark-to-market activity, revenues were affected by unfavorable market conditions in the NEPOOL, ERCOT and PJM markets and an unfavorable wind resource, partly offset by higher operating revenues at PMI and NextEra Energy Resources' retail electricity provider (collectively, approximately $384 million) and project additions ($131 million).

Operating expenses for the year ended December 31, 2010 increased $262 million reflecting higher fuel costs of approximately $366 million, higher costs for project additions of approximately $85 million and higher other operating expenses of $130 million.  Other operating expenses increased due to higher maintenance activities, a write-down in the value of certain assets associated with the plans to repower two California wind facilities and additional wells in gas infrastructure.  This was partially offset by $364 million of unrealized mark-to-market gains from non-qualifying hedges compared to $60 million of such gains in 2009.  Operating expenses for the year ended December 31, 2009 decreased $281 million primarily due to lower fuel costs of approximately $390 million partially offset by proj ect additions of $94 million and higher corporate general and administrative expenses of $21 million to support the growth in the business.  In addition, operating expenses reflect $60 million of unrealized mark-to-market gains from non-qualifying hedges compared to $53 million of such gains in 2008.

NextEra Energy Resources' interest expense for the year ended December 31, 2010 and 2009 increased $55 million and $42 million, respectively, primarily due to increased borrowings to support the growth of the business, partly offset by lower average interest rates of approximately 36 basis points and 37 basis points, respectively.  Gains on disposal of assets - net in NextEra Energy's consolidated statements of income for the year ended December 31, 2010, 2009 and 2008 reflect $49 million, $56 million and $8 million, respectively, of gains on sales of securities held in NextEra Energy Resources' nuclear decommissioning funds.  In addition, gains on disposal of assets - net for the year ended December 31, 2010 reflect a pretax gain of $18 million on the sale of the waste-to-energy proje ct and for the year ended December 31, 2008 reflect an approximately $10 million pretax gain on the sale of development rights related to a natural gas project.

PTCs from NextEra Energy Resources’ wind projects are reflected in NextEra Energy Resources’ earnings.  PTCs are recognized as wind energy is generated and sold based on a per kwh rate prescribed in applicable federal and state statutes, and were approximately $307 million, $255 million and $262 million for the years ended December 31, 2010, 2009 and 2008, respectively.  In addition, NextEra Energy's effective income tax rate for the years ended December 31, 2010 and 2009 was affected by deferred tax benefits associated with convertible ITCs of $68 million and $88 million, respectively.  See Note 6.

41

NextEra Energy Resources expects its future portfolio capacity growth to come primarily from wind and solar development and from asset acquisitions.  NextEra Energy Resources plans to add approximately 3,500 mw to 5,000 mw of new wind generation in 2010 to 2014, including 754 mw added in 2010 and approximately 700 mw to 1,000 mw in 2011.  In addition to wind expansion, NextEra Energy Resources is considering several solar development opportunities in the United States and Europe, and plans to add approximately 400 mw to 600 mw of new solar generation during the period 2010 through 2014, including 5 mw added in 2010.  The wind and solar expansions are subject to, among other things, continued public policy support, support for the construction and availability of sufficient transmission facilities and capa city, continued market demand, supply chain expansion and access to capital at reasonable cost and on reasonable terms.  Currently, in the United States, approximately 30 states and the District of Columbia have RPS requiring electricity providers in the state or district to meet a certain percentage of their retail sales with energy from renewable sources.  These standards vary, but the majority include requirements to meet 10% to 25% of the electricity providers' retail sales with energy from renewable sources by 2025.  NextEra Energy Resources believes that these standards will create incremental demand for renewable energy in the future.

Competitive wholesale markets in the United States continue to evolve and vary among and within geographic regions.  Revenues from electricity sales in these markets vary based on the prices obtainable for energy, capacity and other ancillary services.  Some of the factors affecting success in these markets include the ability to operate generating assets efficiently and reliably, the price and supply of fuel, transmission constraints, wind, solar and hydro resources (weather conditions), competition from regulated utilities and new sources of generation, effective risk management, demand growth, level of demand, environmental requirements and exposure to legal and regulatory changes.

Expanded competition in a frequently changing regulatory environment presents both opportunities and risks for NextEra Energy Resources.  Opportunities exist for the selective acquisition of generation assets and for the construction and operation of efficient plants that can sell power in competitive markets.  NextEra Energy Resources seeks to reduce its market risk by having a diversified portfolio by fuel type and location, as well as by contracting for the future sale of a significant amount of the electricity output of its plants.  The combination of new wind and solar projects and asset acquisitions are expected to be the key drivers supporting NextEra Energy Resources’ growth over the next few years.

NextEra Energy Resources’ earnings are subject to variability due to, among other things, operational performance, commodity price exposure, counterparty performance, weather conditions and project restructuring activities.  NextEra Energy Resources’ exposure to commodity price risk is reduced by the degree of contract coverage obtained for 2011 and 2012.  Therefore, if NextEra Energy Resources’ plants do not perform as expected, NextEra Energy Resources could be required to purchase power at potentially higher market prices to meet its contractual obligations.  In addition to the effect of temperature, which is reflected in commodity prices and demand, changes in weather affect production levels of the wind portfolio as well as the hydro and solar units.  In managing its expos ure to commodity prices, NextEra Energy Resources is dependent upon its counterparties to perform under their contractual obligations.  NextEra Energy Resources actively manages the trade-off between market risk and credit risk, as well as exposure with individual counterparties as a function of their creditworthiness.  As of December 31, 2010, substantially all of NextEra Energy Resources’ 2011 contracted revenues are with investment grade counterparties.

Corporate and Other - Corporate and Other is primarily comprised of interest expense, the operating results of FPL FiberNet and other business activities, as well as corporate interest income and expenses.  Corporate and Other allocates non-utility interest expense and shared service costs to NextEra Energy Resources.  See Summary above and Note 15 for a discussion regarding a change, beginning in 2010, in the method of allocating non-utility interest expense, the allocation of shared service costs and the restatement of the prior year segment results of Corporate and Other.  For purposes of allocating non-utility interest expense, the deferred credit associated with differential membership interests sold by NextEra Energy Resources subsid iaries 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:

	Years Ended December 31,
	2010			2009			2008
				(millions)
Interest expense, net of allocations to NextEra Energy Resources	$	(63	)	$	(43	)	$	(38	)
Interest income		43			34			22
Federal and state income tax benefits		35			-			18
Other		17			34			17
Net income	$	32		$	25		$	19

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The increase in interest expense in 2010 and 2009 reflects additional debt outstanding, partly offset by lower average interest rates of approximately 40 basis points and 66 basis points, respectively, and a higher allocation of interest costs to NextEra Energy Resources.  The increase in interest income in 2010 and 2009 is primarily due to earnings on an energy-related loan made to a third party by a Capital Holdings subsidiary.  The federal and state income tax benefits reflect consolidating income tax adjustments and, in 2010, include a one-time income tax benefit of $24 million related to deferred income taxes.  Other includes all other corporate income and expenses, as well as other business activities.  The decline in other in 2010 is primarily due to an $11 million after-tax loss on the s ale of assets held under leveraged leases; the pretax amount ($17 million) of such loss is reflected in other - net in NextEra Energy's consolidated statements of income.  The increase in other in 2009 primarily reflects realized and unrealized gains on investments which are reflected in other - net in the consolidated statements of income.

Liquidity and Capital Resources

NextEra Energy 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 internally generated funds, short- and long-term borrowings, and the issuance, from time to time, of short- and long-term debt and equity securities, consistent with NextEra Energy's and FPL's objective of maintaining, on a long-term basis, a capital structure that will support a strong investment grade credit rating.  NextEra Energy, FPL and Capital Ho ldings 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 NextEra Energy, FPL and Capital Holdings 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.

The global and domestic credit and capital markets experienced unprecedented levels of volatility and disruption in the recent past.  This significantly affected the cost and available sources of liquidity in the financial markets.  FPL and Capital Holdings have continued to have access to commercial paper and short- and long-term credit and capital markets.  If capital and credit market conditions change, this could alter spending plans and affect working capital at FPL and NextEra Energy Resources.

Available Liquidity - At December 31, 2010, NextEra Energy's total net available liquidity was approximately $6.3 billion, of which FPL's portion was approximately $3.1 billion.  The components of each company's net available liquidity at December 31, 2010 were as follows:

										Maturity Date
	FPL			Capital Holdings			NextEra Energy Consoli- dated			FPL		Capital Holdings
				(millions)
Bank revolving line of credit facilities(a)	$	2,973		$	4,417		$	7,390		(b)		(b)
Less letters of credit		(8	)		(771	)		(779	)
		2,965			3,646			6,611
Revolving credit facility		250			-			250			2014
Less borrowings		-			-			-
		250			-			250
Subtotal		3,215			3,646			6,861
Cash and cash equivalents		20			282			302
Less commercial paper		(101	)		(788	)		(889	)
Net available liquidity	$	3,134		$	3,140		$	6,274

¾¾¾¾¾¾¾¾¾¾

(a)

Provide for the funding of loans up to $7,390 million ($2,973 million for FPL) and the issuance of letters of credit up to $6,390 million ($2,473 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 Capital Holdings' 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 (tax exempt bonds) in the event they are tendered by individual bond holders and not remarketed prior to maturity.

(b)

$17 million of FPL's and $40 million of Capital Holdings' bank revolving line of credit facilities expire in 2012.  The remaining portion of bank revolving line of credit facilities for FPL and Capital Holdings expires in 2013.

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As of February 24, 2011, 58 banks participate in FPL's and Capital Holdings' bank revolving line of credit facilities and FPL's revolving credit facility, with no one bank providing more than 7% of the combined bank revolving line of credit facilities and FPL's revolving credit facility.  Pursuant to a 1998 guarantee agreement, NextEra Energy guarantees the payment of Capital Holdings' debt obligations under the bank revolving line of credit facilities.  As a precondition for Capital Holdings to borrow or to issue letters of credit under the terms of its bank revolving line of credit facilities, among other things, NextEra Energy's ratio of funded debt to total capitalization must not exceed a stated ratio.  The Capital Holdings bank revolving line of credit facilities also contain default and related acceleration provisions relating to, among other things, NextEra Energy's ratio of funded debt to total capitalization exceeding the specified ratio.  Similarly, as a precondition for FPL to borrow or to issue letters of credit under the terms of its bank revolving line of credit facilities and revolving credit facility, among other things, FPL's ratio of funded debt to total capitalization must not exceed a stated ratio.  The FPL bank revolving line of credit facilities and revolving credit facility also contain default and related acceleration provisions relating to, among other things, FPL's ratio of funded debt to total capitalization exceeding the specified ratio.  At December 31, 2010, each of NextEra Energy and FPL was in compliance with its required ratio.

In December 2010, an indirect wholly-owned subsidiary of NextEra Energy Resources (the borrower) entered into two Canadian $150 million, variable rate, three-year bank revolving credit agreements that expire in 2013 (both credit agreements can be extended for up to one additional year with the lenders' consent).  Under one of the credit agreements, if the borrower receives sufficient commitment offers from other interested lenders, the borrower may elect to increase the principal amount of credit available under the credit agreement to an amount not to exceed Canadian $600 million.  Under both credit agreements, subject to satisfying certain preconditions, the borrower has the option at the end of the revolving credit term to convert any outstanding borrowings into a one-year term loan.  Borrowings under the credit agreements can be used for the borrower's general corporate purposes, including the purchase, development, construction, and/or operation of Canadian electricity generating assets, including the repayment of debt assumed in connection with the purchase of such assets.  All borrowings under the credit agreements are guaranteed by Capital Holdings, which payment obligations are in turn guaranteed by NextEra Energy pursuant to the 1998 guarantee agreement with Capital Holdings.  As a precondition to borrow or issue letters of credit under the terms of the credit agreements, among other things, NextEra Energy's ratio of funded debt to total capitalization must not exceed a stated ratio.  The credit agreements also contain default and related acceleration provisions relating to, among other things, NextEra Energy's ratio of funded debt to total capitalization exceeding the specified ratio.  As of December 31, 2010, Canadian $82 million (approximately US $82 million) had been borrowed under one of the credit agreements (see Cash Flow below).  As of February 24, 2011, a total of Canadian $203 million (approximately US $203 million) had been borrowed under the two credit agreements.

Also, two indirect wholly-owned subsidiaries of NextEra Energy Resources have each established an $80 million letter of credit facility.  One of the facilities expires in 2017 and serves as security for certain obligations of the subsidiary under commodity hedge agreements.  The other facility expires in 2018 and serves as security for certain obligations of the subsidiary under power purchase agreements.

In December 2010, NextEra Energy completed the program it commenced in January 2009 under which it offered and sold, from time to time, NextEra Energy common stock having a gross sales price of up to $400 million.  During 2010 and 2009, NextEra Energy received gross proceeds through the sale and issuance of common stock under this program of approximately $240 million and $160 million, respectively.

At December 31, 2010, FPL had the capacity to absorb up to approximately $205 million in future prudently incurred storm restoration costs without seeking recovery through a rate adjustment from the FPSC or filing a petition with the FPSC.  See Note 1 - Revenues and Rates.

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The Dodd-Frank Act was enacted into law in July 2010 which, among other things, provides for the regulation of the OTC derivatives market.  While the legislation is broad and detailed, substantial portions of the legislation require implementing rules to be adopted by federal governmental agencies including, but not limited to, the SEC and the CFTC.  The Dodd-Frank Act generally requires certain OTC derivative transactions (including asset-backed OTC derivatives used to hedge risks associated with commodity and interest rate exposure) to be executed by certain types of entities through an exchange or to be centrally cleared.  However, the Dodd-Frank Act provides an exemption from mandatory clearing requirements for transactions entered into by non-swap dealers or non-major swap participants and other non-financial entities, as defined in the Dodd-Frank Act, that are used to hedge or mitigate commercial risk.  The Dodd-Frank Act also includes provisions under which the CFTC may impose capital and margin requirements on certain entities for transactions, including those that are used to hedge or mitigate commercial risk.  However, key legislators and regulators have indicated that it is not their intention to impose capital and margin requirements on counterparties that are eligible to use transactions to hedge or mitigate commercial risk.  Final rules on OTC derivative-related provisions of the Dodd-Frank Act are required to be established through CFTC and SEC rulemakings within 360 days after the date of enactment.  If, as a result of the rulemaking associated with the Dodd-Frank Act, FPL and NextEra Energy Resources do not qualify for an exemption related to clearing and margining requirements, FPL and NextEra Energy Resources would be subject to higher margin requirements.  It is possible that portions of NextEra Energy Resources' business may be subject to capital, reporting, recordkeeping and business conduct requirements and standards in addition to the already mentioned margin requirements.  Depending on the outcome of these rules, system upgrades and business process modifications would likely be necessary to comply.  NextEra Energy and FPL cannot predict the final rules that will be adopted to implement the OTC derivatives market provisions of the Dodd-Frank Act.  Those rules could negatively affect NextEra Energy’s and FPL’s ability to hedge their commodity and interest rate risks, which could have a material adverse effect on NextEra Energy’s and FPL’s financial results.  The rules also could require NextEra Energy Resources to restructure part of its energy marketing and trading operations or to discontinue certain portions of its business.  In addition, if the rules require NextEra Energy and FPL to post cash collateral with respect to swap transactions, NextEra Energy’ ;s and FPL’s liquidity could be materially adversely affected, and their ability to enter into OTC derivatives to hedge commodity and interest rate risks could be significantly limited.  Reporting and compliance requirements of the rules also could significantly increase operating costs and expose NextEra Energy and FPL to penalties for non-compliance.

Letters of Credit, Surety Bonds and Guarantees - NextEra Energy and FPL obtain letters of credit and surety bonds, and issue guarantees to facilitate commercial transactions with third parties and financings.  At December 31, 2010, NextEra Energy had approximately $977 million of standby letters of credit ($17 million for FPL), approximately $87 million of surety bonds ($51 million for FPL) and approximately $9.5 billion notional amount of guarantees ($43 million for FPL), of which approximately $6.1 billion ($34 million for FPL) letters of credit and guarantees have expiration dates within the next five years.  An aggregate of approximately $779 million ($8 million for FPL) of the standby letters of credit at December 31, 2010 were issued under FPL 's and Capital Holdings' credit facilities.  See Available Liquidity above.  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 wind development and other contractual agreements.  Each of NextEra Energy and FPL believe it is unlikely that it would incur any liabilities associated with these letters of credit, surety bonds and guarantees.  Accordingly, at December 31, 2010, NextEra Energy and FPL did not have any liabilities recorded for these letters of credit, surety bonds and guarantees.  In addition, NextEra Energy has guaranteed certain payment obligations of Capital Holdings, including most of its debt and all of its debentures and commercial paper issuances, as well as most of its payment guarantees, and Capital Holdings has guaranteed certain debt and other obligations of NextEra Energy Resources and its subsidiaries.  See Note 14 - Commitments.

Shelf Registration - In August 2009, NextEra Energy, Capital Holdings, FPL and certain affiliated trusts filed a shelf registration statement with the SEC for an unspecified amount of securities.  The amount of securities issuable by the companies is established from time to time by their respective boards of directors.  As of February 24, 2011, securities that may be issued under the registration statement, which became effective upon filing, include, depending on the registrant, senior debt securities, subordinated debt securities, junior subordinated debentures, first mortgage bonds, preferred trust securities, common stock, preferred stock, stock purchase contracts, stock purchase units, warrants and guarantees related to certain of those securities.   As of February 24, 2011, NextEra Energy and Capital Holdings had approximately $2.7 billion (issuable by either or both of them up to such aggregate amount) of board-authorized available capacity, and FPL had $1.6 billion of board-authorized available capacity.

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Credit Ratings - NextEra Energy's and FPL's liquidity, ability to access credit and capital markets, cost of borrowings and collateral posting requirements under certain agreements are dependent on their credit ratings.  At February 24, 2011, Moody's Investors Service, Inc. (Moody's), Standard & Poor's Ratings Services (S&P) and Fitch Ratings (Fitch) had assigned the following credit ratings to NextEra Energy, FPL and Capital Holdings:

	Moody's(a)	S&P(a)	Fitch(a)
NextEra Energy:(b)
Corporate credit rating	Baa1	A-	A-
FPL:(b)
Corporate credit rating	A2	A-	A
First mortgage bonds	Aa3	A	AA-
Pollution control, solid waste disposal and industrial development revenue bonds	VMIG-1	A	A+
Commercial paper	P-1	A-2	F1
Capital Holdings:(b)
Corporate credit rating	Baa1	A-	A-
Debentures	Baa1	BBB+	A-
Junior subordinated debentures	Baa2	BBB	BBB
Commercial paper	P-2	A-2	F1

¾¾¾¾¾¾¾¾¾¾

(a)	A security rating is not a recommendation to buy, sell or hold securities and should be evaluated independently of any other rating.  The rating is subject to revision or withdrawal at any time by the assigning rating organization.
(b)	The outlook indicated by Moody's, S&P and Fitch is stable, stable and negative, respectively.

NextEra Energy and its subsidiaries, including FPL, have no credit rating downgrade triggers that would accelerate the maturity dates of outstanding debt.  A change in ratings is not an event of default under applicable debt instruments, and while there are conditions to drawing on the FPL, Capital Holdings and Canadian credit facilities, the maintenance of a specific minimum credit rating is not a condition to drawing on these credit facilities.  Commitment fees and interest rates on loans under these credit facilities' agreements are tied to credit ratings.  A ratings downgrade also could reduce the accessibility and increase the cost of commercial paper and other short-term debt issuances and additional or replacement credit facilities.  In addition, a ratings downgrade could result in the re quirement that NextEra Energy subsidiaries, including FPL, post collateral under certain agreements, including those related to fuel procurement, power sales and purchases, nuclear decommissioning funding, debt-related reserves and trading activities.  FPL's and Capital Holdings' credit facilities are available to support these potential requirements.  See Available Liquidity above.

Cash Flow - The changes in cash and cash equivalents are summarized as follows:

	NextEra Energy										FPL
	Years Ended December 31,
	2010			2009			2008				2010				2009			2008
							(millions)
Net cash provided by operating activities	$	3,834		$	4,463			$	3,403			$	1,934		$	2,871		$	2,180
Net cash used in investing activities		(5,284	)		(5,935	)			(5,808	)			(2,561	)		(2,726	)		(2,427	)
Net cash provided by (used in) financing activities		1,514			1,175				2,650				564			(182	)		304
Net increase (decrease) in cash and cash equivalents	$	64		$	(297	)		$	245			$	(63	)	$	(37	)	$	57

NextEra Energy's cash and cash equivalents increased for the year ended December 31, 2010 reflecting cash generated by operating activities, net issuances of long-term debt, issuance of common stock, proceeds from the sale of differential membership interests and cash grants received under the Recovery Act.  These inflows were partially offset by capital investments by FPL and NextEra Energy Resources, a net decrease in short-term debt and the payment of common stock dividends to NextEra Energy shareholders.

NextEra Energy's cash flows from operating activities for the year ended December 31, 2010 reflect cash generated by net income and derivative-related activities, including margin cash collateral provided from NextEra Energy Resources' counterparties as a result of changing energy prices, prepaid option premiums and settlements.  These inflows were partially offset by cash outflows related to FPL's cost recovery clauses and franchise fees, primarily the fuel clause.

NextEra Energy's cash flows from investing activities for the year ended December 31, 2010 reflect capital investments, including nuclear fuel purchases, of approximately $2.7 billion by FPL to expand and enhance its electric system and generating facilities to continue to provide reliable service to meet the power needs of present and future customers and investments in independent power projects, including nuclear fuel, of approximately $3.1 billion by NextEra Energy Resources.  NextEra Energy's cash flows from investing activities also include approximately $588 million (comprised of $427 million and $161 million at NextEra Energy Resources and FPL, respectively) of cash grants under the Recovery Act, the purchase and sale of restricted securities held in the special use funds, including the reinvestment of fund earn ings and new contributions by NextEra Energy Resources, as well as other investment activity, primarily at Capital Holdings.  NextEra Energy expects to receive additional cash grants under the Recovery Act during 2011.

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During the year ended December 31, 2010, NextEra Energy generated proceeds from financing activities of approximately $4.3 billion, including $261 million in proceeds from the sale of differential membership interests, $308 million in proceeds from the issuance of common stock, primarily under NextEra Energy’s continuous offering agreement (see Available Liquidity above), and the following long-term debt issuances and borrowings:

Date Issued	Company	Debt Issuances/Borrowings	Interest Rate		Principal Amount			Maturity Date
					(millions)
February 2010	FPL	First mortgage bonds	5.69%		$	500		2040
March 2010	NextEra Energy Resources subsidiary	Senior secured limited recourse notes	6.56%			305		2030
April 2010	Capital Holdings	Term loan	Variable	(a)		100		2013
April 2010	Capital Holdings	Term loan	Variable	(a)		100		2013
April 2010	NextEra Energy Resources subsidiary	Senior secured limited recourse term loan	Variable	(a)(b)		255		2027
May 2010	Capital Holdings	Debentures	2.55%	(b)		250		2013
June 2010	NextEra Energy Resources subsidiary	Limited recourse term loan	Variable	(a)		78		2015
August 2010	Capital Holdings	Debentures	2.60%	(b)		400		2015
September 2010	Capital Holdings	Term loan	Variable	(a)		50		2013
September 2010	Capital Holdings	Debentures related to NextEra Energy's equity units	1.90%			403		2015
September 2010	Capital Holdings	Japanese yen denominated senior notes	5.1325%	(c)		120	(c)	2030
September 2010	NextEra Energy Resources subsidiary	Senior secured limited recourse term loan	Variable	(a)(b)		297		2028
September 2010	Capital Holdings	Term loan	Variable	(a)		50		2013
September 2010	Capital Holdings	Term loan	Variable	(a)		110		2014
December 2010	FPL	First mortgage bonds	5.25%			400		2041
December 2010	NextEra Energy Resources subsidiary	Canadian revolving credit facility	Variable	(a)		82		2013
December 2010	NextEra Energy Resources subsidiary	Senior secured limited recourse term loan	Variable	(a)(b)		231		2018
					$	3,731

¾¾¾¾¾¾¾¾¾¾

(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.
(c)	Reflects a currency swap agreement entered into with respect to both interest and principal payments on this issuance.

On April 30, 2010, Peace Garden Wind Funding, LLC, an indirect wholly-owned subsidiary of NextEra Energy Resources, sold its Class B membership interests in Peace Garden Wind, LLC, an indirect wholly-owned subsidiary of NextEra Energy Resources with ownership interests in two wind generation facilities with generating capability totaling approximately 170 mw located in North Dakota, to certain third-party investors for approximately $190 million.

On September 30, 2010, Heartland Wind Funding, LLC (Heartland Wind Funding), an indirect wholly-owned subsidiary of NextEra Energy Resources, sold Class B membership interests in Heartland Wind, LLC (Heartland Wind), an indirect wholly-owned subsidiary of NextEra Energy Resources, with ownership interests in three wind generation facilities with generating capability totaling approximately 309 mw located in North Dakota and Iowa, to a third-party investor.  At closing, Heartland Wind Funding received approximately $71 million and will receive future capital contributions from the third-party investor on a semi-annual basis through December 31, 2018 based on the amount of PTCs generated by Heartland Wind.  At December 31, 2010, the future capital contributions are expected to total approximately $207 milli on based on projected wind generation.

During the year ended December 31, 2010, NextEra Energy paid approximately $2.7 billion in connection with financing activities, including $357 million in principal payments on NextEra Energy Resources' debt, $370 million in principal payments on Capital Holdings' debt, $42 million in principal payments on FPL's storm-recovery bonds, a net decrease in short-term debt of $1.1 billion (comprised of $414 million and $717 million at Capital Holdings and FPL, respectively) and $823 million for the payment of dividends on NextEra Energy's common stock.

NextEra Energy's cash and cash equivalents decreased for the year ended December 31, 2009 reflecting capital investments by FPL and NextEra Energy Resources, the payment of common stock dividends to NextEra Energy shareholders and margin cash collateral provided to NextEra Energy Resources' derivative instrument counterparties.  These outflows were partially offset by cash generated by operating activities, net issuances of both long- and short-term debt and the issuance of common stock.

47

Contractual Obligations and Estimated Planned Capital Expenditures - NextEra Energy's and FPL's commitments at December 31, 2010 were as follows:

	2011		2012		2013		2014		2015		Thereafter				Total
	(millions)
Long-term debt, including interest:(a)
FPL	$	389	$	391	$	782	$	373	$	374		$	12,143	(b)	$	14,452
NextEra Energy Resources		709		715		839		579		677			4,220			7,739
Corporate and Other		1,885		719		1,157		881		1,605			12,417			18,664
Purchase obligations:
FPL(c)		6,190		5,330		3,390		2,890		2,645			10,270			30,715
NextEra Energy Resources(d)		1,175		225		175		160		160			725			2,620
Asset retirement activities:(e)
FPL(f)		-		-		-		-		-			7,106			7,106
NextEra Energy Resources(g)		2		2		-		-		-			9,736			9,740
Other Commitments:
NextEra Energy Resources(h)		14		5		72		73		98			490			752
Total	$	10,364	$	7,387	$	6,415	$	4,956	$	5,559		$	57,107		$	91,788

¾¾¾¾¾¾¾¾¾¾

(a)	Includes principal, interest and interest rate swaps.  Variable rate interest was computed using December 31, 2010 rates.
(b)	Includes $633 million of tax exempt bonds that permit individual bond holders to tender the bonds for purchase at any time prior to maturity.  In the event bonds are tendered for purchase, they would be remarketed by a designated remarketing agent in accordance with the related indenture.  If the remarketing is unsuccessful, FPL would be required to purchase the tax exempt bonds.  As of December 31, 2010, all tax exempt bonds tendered for purchase have been successfully remarketed.  FPL's bank revolving line of credit facilities are available to support the purchase of tax exempt bonds.
(c)	Represents required capacity and minimum payments under long-term purchased power and fuel contracts (see Note 14 - Contracts), and projected capital expenditures through 2015 (see Note 14 - Commitments).
(d)	Represents firm commitments primarily in connection with construction activities, and fuel-related and transmission service contracts.  See Note 14 - Commitments and Contracts.
(e)	Represents expected cash payments adjusted for inflation for estimated costs to perform asset retirement activities.
(f)	At December 31, 2010, FPL had approximately $2,512 million in restricted funds for the payment of future expenditures to decommission FPL's nuclear units, which are included in NextEra Energy's and FPL's special use funds.  See Note 13.
(g)	At December 31, 2010, NextEra Energy Resources' 88.23% portion of Seabrook's and 70% portion of Duane Arnold's and its Point Beach's restricted funds for the payment of future expenditures to decommission its nuclear units totaled approximately $1,105 million and are included in NextEra Energy's special use funds.  See Note 13.
(h)	Represents estimated cash distributions related to membership interests and payments related to the acquisition of certain development rights.  For further discussion of membership interests, see Note 1 - Sale of Differential Membership Interests.

Covenants - NextEra Energy's charter does not limit the dividends that may be paid on its common stock.  As a practical matter, the ability of NextEra Energy to pay dividends on its common stock is dependent upon, among other things, dividends paid to it by its subsidiaries.  During the first quarter of 2010, NextEra Energy increased the quarterly dividend on its common stock from $0.4725 to $0.50 per share.  In February 2011, NextEra Energy announced that it would increase the quarterly dividend on its common stock from $0.50 to $0.55 per share.  FPL pays dividends to NextEra Energy in a manner consistent with FPL's long-term targeted capital structure.  The mortgage securing FPL's first mortgage bonds contains provisions which, under certain conditions, restrict the payment of dividends to NextEra Energy and the issuance of additional first mortgage bonds.  In light of FPL's current financial condition and level of earnings, management does not expect that planned financing activities or dividends would be affected by these limitations.

Under the mortgage, in some cases, the amount of retained earnings that FPL can use to pay cash dividends on its common stock is restricted.  The restricted amount may change based on factors set out in the mortgage.  Other than this restriction on the payment of common stock dividends, the mortgage does not restrict FPL's use of retained earnings.  As of December 31, 2010, no retained earnings were restricted by these provisions of the mortgage.

FPL may issue first mortgage bonds under its mortgage subject to its meeting an adjusted net earnings test set forth in the mortgage, which generally requires adjusted net earnings to be at least twice the annual interest requirements on, or at least 10% of the aggregate principal amount of, FPL's first mortgage bonds including those to be issued and any other non-junior FPL indebtedness.  As of December 31, 2010, coverage for the 12 months ended December 31, 2010 would have been approximately 6.3 times the annual interest requirements and approximately 3.6 times the aggregate principal requirements.  New first mortgage bonds are also limited to an amount equal to the sum of 60% of unfunded property additions after adjustments to offset property retirements, the amount of retired first mortgage bonds or q ualified lien bonds and the amount of cash on deposit with the mortgage trustee.  As of December 31, 2010, FPL could have issued in excess of $8.1 billion of additional first mortgage bonds based on the unfunded property additions and in excess of $5.8 billion based on retired first mortgage bonds.  As of December 31, 2010, no cash was deposited with the mortgage trustee for these purposes.

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In September 2006, NextEra Energy and Capital Holdings executed a Replacement Capital Covenant (September 2006 RCC) in connection with Capital Holdings' offering of $350 million principal amount of Series A Enhanced Junior Subordinated Debentures due 2066 and $350 million principal amount of Series B Enhanced Junior Subordinated Debentures due 2066 (collectively, Series A and Series B junior subordinated debentures).  The September 2006 RCC is for the benefit of persons that buy, hold or sell a specified series of long-term indebtedness (covered debt) of Capital Holdings (other than the Series A and Series B junior subordinated debentures) or, in certain cases, of NextEra Energy.  FPL Group Capital Trust I's 5 7/8% Preferred Trust Securities have been initially designated as the covered debt under the September 200 6 RCC.  The September 2006 RCC provides that Capital Holdings may redeem, and NextEra Energy or Capital Holdings may purchase, any Series A and Series B junior subordinated debentures on or before October 1, 2036, only to the extent that the redemption or purchase price does not exceed a specified amount of proceeds from the sale of qualifying securities, subject to certain limitations described in the September 2006 RCC.  Qualifying securities are securities that have equity-like characteristics that are the same as, or more equity-like than, the Series A and Series B junior subordinated debentures at the time of redemption or purchase, which are sold within 180 days prior to the date of the redemption or repurchase of the Series A and Series B junior subordinated debentures.

In June 2007, NextEra Energy and Capital Holdings executed a Replacement Capital Covenant (June 2007 RCC) in connection with Capital Holdings' offering of $400 million principal amount of its Series C Junior Subordinated Debentures due 2067 (Series C junior subordinated debentures).  The June 2007 RCC is for the benefit of persons that buy, hold or sell a specified series of covered debt of Capital Holdings (other than the Series C junior subordinated debentures) or, in certain cases, of NextEra Energy.  FPL Group Capital Trust I's 5 7/8% Preferred Trust Securities have been initially designated as the covered debt under the June 2007 RCC.  The June 2007 RCC provides that Capital Holdings may redeem or purchase, or satisfy, discharge or defease (collectively, defease), and NextEra Energy and any majority- owned subsidiary of NextEra Energy or Capital Holdings may purchase, any Series C junior subordinated debentures on or before June 15, 2037, only to the extent that the principal amount defeased or the applicable redemption or purchase price does not exceed a specified amount raised from the issuance, during the 180 days prior to the date of that redemption, purchase or defeasance, of qualifying securities that have equity-like characteristics that are the same as, or more equity-like than, the applicable characteristics of the Series C junior subordinated debentures at the time of redemption, purchase or defeasance, subject to certain limitations described in the June 2007 RCC.

In September 2007, NextEra Energy and Capital Holdings executed a Replacement Capital Covenant (September 2007 RCC) in connection with Capital Holdings' offering of $250 million principal amount of its Series D Junior Subordinated Debentures due 2067 and $350 million principal amount of Series E Junior Subordinated Debentures due 2067 (collectively, Series D and Series E junior subordinated debentures).  The September 2007 RCC is for the benefit of persons that buy, hold or sell a specified series of covered debt of Capital Holdings (other than the Series D and Series E junior subordinated debentures) or, in certain cases, of NextEra Energy.  FPL Group Capital Trust I's 5 7/8% Preferred Trust Securities have been initially designated as the covered debt under the September 2007 RCC.  The September 2007 RC C provides that Capital Holdings may redeem, purchase, or defease, and NextEra Energy and any majority-owned subsidiary of NextEra Energy or Capital Holdings may purchase, any Series D and Series E junior subordinated debentures on or before September 1, 2037, only to the extent that the principal amount defeased or the applicable redemption or purchase price does not exceed a specified amount raised from the issuance, during the 180 days prior to the date of that redemption, purchase or defeasance, of qualifying securities that have equity-like characteristics that are the same as, or more equity-like than, the applicable characteristics of the Series D and Series E junior subordinated debentures at the time of redemption, purchase or defeasance, subject to certain limitations described in the September 2007 RCC.

In March 2009, NextEra Energy and Capital Holdings executed a Replacement Capital Covenant (March 2009 RCC) in connection with Capital Holdings' offering of $375 million principal amount of its Series F Junior Subordinated Debentures due 2069.  The March 2009 RCC is for the benefit of persons that buy, hold or sell a specified series of covered debt of Capital Holdings (other than the Series F junior subordinated debentures) or, in certain cases, of NextEra Energy.  FPL Group Capital Trust I's 5 7/8% Preferred Trust Securities have been initially designated as the covered debt under the March 2009 RCC.  The March 2009 RCC provides that Capital Holdings may redeem, purchase, or defease, and NextEra Energy and any majority-owned subsidiary of NextEra Energy or Capital Holdings may purchase, any Series F jun ior subordinated debentures on or before March 1, 2039, only to the extent that the principal amount defeased or the applicable redemption or purchase price does not exceed a specified amount raised from the issuance, during the 180 days prior to the date of that redemption, purchase or defeasance, of qualifying securities that have equity-like characteristics that are the same as, or more equity-like than, the applicable characteristics of the Series F junior subordinated debentures at the time of redemption, purchase or defeasance, subject to certain limitations described in the March 2009 RCC.

Critical Accounting Policies and Estimates

NextEra Energy's and FPL's significant accounting policies are described in Note 1 to the consolidated financial statements, which were prepared in accordance with accounting principles generally accepted in the United States.  Critical accounting policies are those that NextEra Energy and FPL believe are both most important to the portrayal of their financial condition and results of operations, and require complex, subjective judgments, often as a result of the need to make estimates and assumptions about the effect of matters that are inherently uncertain.  Judgments and uncertainties affecting the application of those policies may result in materially different amounts being reported under different conditions or using different assumptions.

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NextEra Energy and FPL consider the following policies to be the most critical in understanding the judgments that are involved in preparing their consolidated financial statements:

Accounting for Derivatives and Hedging Activities - NextEra Energy 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.  In addition, NextEra Energy, through NextEra Energy Resources, uses derivatives to optimize the value of power generation assets.  NextEra Energy Resources provides full energy and capacity requirements services primarily to distribution utilities, which include load-following services and various ancillary services, in certain markets and engages in power and gas marketing and trading activities to take a dvantage of expected future favorable price movements.  Accounting pronouncements, which require the use of fair value accounting if certain conditions are met, apply not only to traditional financial derivative instruments, but to any contract having the accounting characteristics of a derivative.

Derivative instruments, when required to be marked to market, are recorded on the balance sheet at fair value.  Fair values for some of the longer-term contracts where liquid markets are not available are based on internally developed models based on the forward prices for electricity and fuel.  Forward prices represent the price at which a buyer or seller could contract today to purchase or sell a commodity at a future date.  In general, the models estimate the fair value of a contract by calculating the present value of the difference between the contract price and the forward prices.  The near term forward market for electricity is generally liquid and therefore the prices in the early years of the forward curves reflect observable market quotes.  However, in the later years, the ma rket is much less liquid and forward price curves must be developed using factors including the forward prices for the commodities used as fuel to generate electricity, the expected system heat rate (which measures the efficiency of power plants in converting fuel to electricity) in the region where the purchase or sale takes place, and a fundamental forecast of expected spot prices based on modeled supply and demand in the region.  The assumptions in these models are critical since any changes therein could have a significant impact on the fair value of the contract.  Substantially all changes in the fair value of derivatives held by FPL are deferred as a regulatory asset or liability until the contracts are settled.  Upon settlement, any gains or losses will be passed through the fuel or capacity clauses.  In NextEra Energy's non-rate regulated operations, predominantly NextEra Energy Resources, changes in derivative fair values are recognized in current earnings, un less the criteria for hedge accounting are met and the company elects to account for the derivative as a hedge.  For those transactions accounted for as cash flow hedges, much of the effects of changes in fair value are reflected in other comprehensive income (OCI), a component of common shareholders' equity, rather than being recognized in current earnings.  For those transactions accounted for as fair value hedges, the effects of changes in fair value are reflected in current earnings offset by changes in the fair value of the item being hedged.

Much of the existing accounting guidance related to derivatives focuses on when certain contracts for the purchase and sale of power and certain fuel supply contracts can be excluded from derivative accounting rules, however the guidance does not address all contract issues.  As a result, significant judgment must be used in applying derivatives accounting guidance to contracts.  In the event changes in interpretation occur, it is possible that contracts that currently are excluded from derivatives accounting rules would have to be recorded on the balance sheet at fair value, with changes in the fair value recorded in the statement of income.

Certain economic hedging transactions at NextEra Energy Resources do not meet the requirements for hedge accounting treatment.  Changes in the fair value of those transactions are marked to market and reported in the statement of income, often resulting in earnings volatility.  These changes in fair value are captured in the non-qualifying hedge category in computing adjusted earnings.  This could be significant to NextEra Energy Resources' results because often 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, net income reflects only the movement in one part of economically linked transactions.  Because of this, NextEra Energy's management views result s expressed excluding the unrealized mark-to-market impact of the non-qualifying hedges as a meaningful measure of current period performance.  For additional information regarding derivative instruments, see Note 3, Results of Operations and Energy Marketing and Trading and Market Risk Sensitivity.

Accounting for Pensions and Other Postretirement Benefits - NextEra Energy sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NextEra Energy and its subsidiaries.  NextEra Energy also has a supplemental executive retirement plan (SERP) which includes a non-qualified supplemental defined benefit pension component that provides benefits to a select group of management and highly compensated employees.  The impact of the SERP component is included within the pension plan as discussed below.  In addition to pension benefits, NextEra Energy sponsors a contributory postretirement plan for health care and life insurance benefits (other benefits plan) for retirees of NextEra Energy and its subsidiaries meeti ng certain eligibility requirements.  The qualified pension plan has a fully funded trust dedicated to providing the benefits under the plan.  The other benefits plan has a partially funded trust dedicated to providing benefits related to life insurance.  NextEra Energy allocates net periodic benefit income or cost associated with the pension and other benefits plans to its subsidiaries annually using specific criteria.

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NextEra Energy's regulatory assets and liabilities were established in association with the implementation of accounting guidance in a prior year which requires recognition of the funded status of benefit plans in the balance sheet, with changes in the funded status recognized in comprehensive income within shareholders' equity in the year in which the changes occur.  Since NextEra Energy is the plan sponsor, and its subsidiaries do not have separate rights to the plan assets or direct obligations to their employees, the results of implementing the accounting guidance were reflected at NextEra Energy and not allocated to the subsidiaries.  The portion of previously unrecognized actuarial gains and losses, prior service costs or credits and transition obligations that were estimated to be allocable to FPL as net periodic benefit (income) cost in future periods and that otherwise would have been recorded in accumu lated other comprehensive income (AOCI) were classified as regulatory assets and liabilities at NextEra Energy in accordance with regulatory treatment.

NextEra Energy's income from its pension plan, net of the cost of the other benefits plan, was approximately $38 million, $75 million and $86 million for the years ended December 31, 2010, 2009 and 2008, respectively.  The corresponding amounts allocated to FPL were $19 million, $50 million and $60 million, respectively.  Pension income and the cost of the other benefits plan are included in O&M expenses, and are calculated using a number of actuarial assumptions.  Those assumptions include an expected long-term rate of return on qualified plan assets of 7.75% for all years for the pension plan and 8.00% for all years for the other benefits plan, assumed increases in salary of 4.00% for all years, and weighted-average discount rates of 5.50%, 6.90% and 6.25% for the pension plan and 5.50%, 6.90% and 6.35% for the other benefits plan for the years ended December 31, 2010, 2009 and 2008, respectively.  Based on current health care costs (as related to other benefits), the projected 2010 trend assumption used to measure the expected cost of health care benefits covered by the plans for those under age 65 is 7.60% for medical and 8.20% for prescription drug benefits and for those age 65 and over is 7.25% for medical and 7.75% for prescription drug benefits.  These rates are assumed to decrease over the next 8 years for medical benefits and 10 years for prescription drug benefits to the ultimate trend rate of 5.50% and remain at that level thereafter.  The ultimate trend rate is assumed to be reached in 2018 for medical benefits and 2020 for prescription drug benefits.  In developing these assumptions, NextEra Energy evaluated input from its actuaries, as well as information available in the marketplace.  For the expected long-term rate of return on fund assets, NextEra Energy considered 10-year and 20-year historical median returns for a portfolio with an equity/bond asset mix similar to its funds, as well as its funds' historical compounded returns.  NextEra Energy also considered input from its actuaries and consultants, as well as information available in the marketplace.  NextEra Energy believes that 7.75% and 8.00% are reasonable long-term rates of return on its pension plan and other benefits plan assets, respectively.  NextEra Energy will continue to evaluate all of its actuarial assumptions, including its expected rate of return, at least annually, and will adjust them as necessary.

NextEra Energy bases its determination of pension and other benefits plan expense or income on a market-related valuation of assets, which reduces year-to-year volatility.  This market-related valuation recognizes investment gains or losses over a five-year period following the year in which they occur.  Investment gains or losses for this purpose are the difference between the expected return calculated using the market-related value of assets and the actual return realized on those assets.  Since the market-related value of assets recognizes gains or losses over a five-year period, the future value of assets will be affected as previously deferred gains or losses are recognized.  Such gains and losses together with other differences between actual results and the estimates used in the actuaria l valuations are deferred and recognized in determining pension and other benefits plan expense and income only to the extent they exceed 10% of the greater of projected benefit obligations or the market-related value of assets.

The following table illustrates the effect on net periodic benefit income of changing the critical actuarial assumptions discussed above, while holding all other assumptions constant:

				Decrease in 2010 Net Periodic Benefit Income
	Change in Assumption			NextEra Energy		FPL
				(millions)
Expected long-term rate of return	(0.5	)	%	$	16	$	11
Discount rate	(0.5	)	%	$	-	$	-
Salary increase	0.5		%	$	2	$	1
Health care cost trend rate(a)	1.0		%	$	1	$	1

¾¾¾¾¾¾¾¾¾¾

(a) Assumed health care cost trend rates can have a significant effect on the amounts reported for postretirement plans providing health care benefits.  However, this effect is somewhat mitigated by the retiree cost sharing structure incorporated in NextEra Energy's other benefits plan.

The fair value of plan assets has increased from $3.0 billion at December 31, 2009 to $3.2 billion at December 31, 2010 for the pension plan and remained constant at $32 million at December 31, 2009 and 2010 for the other benefits plan.  Management believes that, based on the actuarial assumptions and the well funded status of the pension plan, NextEra Energy will not be required to make any cash contributions to the qualified pension plan in the near future.  In December 2010, $29 million was transferred from the qualified pension plan as reimbursement for eligible retiree medical expenses paid by NextEra Energy during the year pursuant to the provisions of the Internal Revenue Code.  NextEra Energy anticipates paying approximately $28 million for eligible retiree medical expenses on behal f of the other benefits plan during 2011 with substantially all of that amount being reimbursed through a transfer of assets from the qualified pension plan.  See Note 2.

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Carrying Value of Long-Lived Assets -NextEra Energy evaluates on an ongoing basis the recoverability of its assets for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable.  An impairment loss is required to be recognized if the carrying value of the asset exceeds the undiscounted future net cash flows associated with that asset.  The impairment loss to be recognized is the amount by which the carrying value of the long-lived asset exceeds the asset's fair value.  In most instances, the fair value is determined by discounting estimated future cash flows using an appropriate interest rate.

The amount of future net cash flows, the timing of the cash flows and the determination of an appropriate interest rate all involve estimates and judgments about future events.  In particular, the aggregate amount of cash flows determines whether an impairment exists, and the timing of the cash flows is critical in determining fair value.  Because each assessment is based on the facts and circumstances associated with each long-lived asset, the effects of changes in assumptions cannot be generalized.

Nuclear Decommissioning and Fossil/Solar Dismantlement - The components of NextEra Energy's and FPL's decommissioning of nuclear plants, dismantlement of plants and other accrued asset removal costs are as follows:

	FPL
	Nuclear Decommissioning						Fossil/Solar Dismantlement						Interim Removal Costs and Other						NextEra Energy Resources				NextEra Energy
	December 31,						December 31,						December 31,						December 31,				December 31,
	2010			2009			2010			2009			2010			2009			2010		2009		2010		2009
	(millions)
AROs	$	1,057		$	1,807		$	23		$	23		$	3		$	3		$	556	$	585	$	1,639	$	2,418
Less capitalized ARO asset net of accumulated depreciation		-			50			4			5			-			-			-		-		4		55
Accrued asset removal costs(a)		207			196			336			318			1,701			1,737			-		-		2,244		2,251
Asset retirement obligation regulatory expense difference(a)		1,571			644			22			28			(1	)		(1	)		-		-		1,592		671
Accrued decommissioning, dismantlement and other accrued asset removal costs	$	2,835	(b)	$	2,597	(b)	$	377	(b)	$	364	(b)	$	1,703	(b)	$	1,739	(b)	$	556	$	585	$	5,471	$	5,285

¾¾¾¾¾¾¾¾¾¾

(a)	Regulatory liability on NextEra Energy's and FPL's consolidated balance sheets.
(b)	Represents total amount accrued for ratemaking purposes.

NextEra Energy and FPL each account for asset retirement obligations and conditional asset retirement obligations (collectively, AROs) under accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated, with the offsetting associated asset retirement costs capitalized as part of the carrying amount of the long-lived assets.  See Note 1 - Asset Retirement Obligations, Note 1 - Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs and Note 13.

For ratemaking purposes, FPL accrues and funds for nuclear plant decommissioning costs over the expected service life of each unit based on studies that are filed with the FPSC at least every five years.  The most recent studies, filed in 2010, indicate that FPL's portion of the future cost of decommissioning its four nuclear units, including spent fuel storage above what is expected to be refunded by the DOE under the spent fuel settlement agreement, is approximately $6.2 billion, or $2.3 billion in 2010 dollars.  The studies reflect, among other things, the expiration dates of the operating licenses for FPL's nuclear units.  FPL accrues the cost of dismantling its fossil and solar plants over the expected service life of each unit based on studies filed with the FPSC.  Unlike nuclear decommiss ioning, dismantlement costs are not funded.  The most recent studies became effective January 1, 2010.  At December 31, 2010, FPL's portion of the ultimate cost to dismantle its fossil and solar units is approximately $860 million, or $455 million expressed in 2010 dollars.  The majority of the dismantlement costs are not considered AROs.  In addition, FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC.  Any differences between the ARO amount recorded and the amount recorded for ratemaking purposes are reported as a regulatory liability in accordance with regulatory accounting.

NextEra Energy Resources records a liability for the present value of its expected decommissioning costs which is determined using various internal and external data and applying a probability percentage to a variety of scenarios regarding the life of the plant and timing of decommissioning.  The liability is being accreted using the interest method through the date decommissioning activities are expected to be complete.  At December 31, 2010, the ARO for nuclear decommissioning of NextEra Energy Resources' nuclear plants totaled approximately $478 million.  NextEra Energy Resources' portion of the ultimate cost of decommissioning its nuclear plants, including costs associated with spent fuel storage above what is expected to be refunded by the DOE under the spent fuel settlement agreement, is estima ted to be approximately $9.5 billion, or $1.8 billion expressed in 2010 dollars.

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The calculation of the future cost of retiring long-lived assets, including nuclear decommissioning and fossil and solar dismantlement costs, involves estimating the amount and timing of future expenditures and making judgments concerning whether or not such costs are considered a legal obligation.  Estimating the amount and timing of future expenditures includes, among other things, making projections of when assets will be retired and ultimately decommissioned and how costs will escalate with inflation.  In addition, NextEra Energy and FPL also make interest rate and rate of return projections on their investments in determining recommended funding requirements for nuclear decommissioning costs.  Periodically, NextEra Energy and FPL are required to update these estimates and projections which can affect the annual expense amounts recognized, the liabilities recorded and the annual funding requirements for nuclear decommissioning costs.  For example, an increase of 0.25% in the assumed escalation rates would increase NextEra Energy's and FPL's ARO as of December 31, 2010 by $133 million and $82 million, respectively.

Regulatory Accounting -Accounting guidance allows regulators to create assets and impose liabilities that would not be recorded by non-rate regulated entities.  Regulatory assets and liabilities represent probable future revenues that will be recovered from or refunded to customers through the ratemaking process.  If FPL were no longer subject to cost-based rate regulation, the existing regulatory assets and liabilities would be written off unless regulators specify an alternative means of recovery or refund.  In addition, the FPSC has the authority to disallow recovery of costs that it considers excessive or imprudently incurred.  Such costs may include, among others, fuel and O&M expenses, the cost of replacing power lost when fossil and nuclear units are unavailable, storm restoration costs and costs associated with the construction or acquisition of new facilities.  The continued applicability of regulatory accounting is assessed at each reporting period.

NextEra Energy's and FPL's regulatory assets and liabilities are as follows:

	NextEra Energy				FPL
	December 31,				December 31,
	2010		2009		2010		2009
Regulatory assets:	(millions)
Current:
Deferred clause and franchise expenses	$	368	$	69	$	368	$	69
Derivatives	$	236	$	68	$	236	$	68
Other	$	82	$	72	$	76	$	69
Noncurrent:
Securitized storm-recovery costs	$	581	$	644	$	581	$	644
Other	$	329	$	265	$	293	$	214
Regulatory liabilities:
Current:
Deferred clause and franchise revenues	$	47	$	377	$	47	$	377
Other	$	4	$	2	$	-	$	-
Noncurrent:
Accrued asset removal costs	$	2,244	$	2,251	$	2,244	$	2,251
Asset retirement obligation regulatory expense difference	$	1,592	$	671	$	1,592	$	671
Other	$	423	$	260	$	377	$	244

All regulatory assets and liabilities are included in rate base or otherwise earn (pay) a return on investment during the recovery period.  See Note 1 for a discussion of NextEra Energy's and FPL's other significant accounting policies.

Energy Marketing and Trading and Market Risk Sensitivity

Energy Marketing and Trading - Certain of NextEra Energy's subsidiaries, including FPL and NextEra Energy Resources, 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, NextEra Energy, through NextEra Energy Resources, uses derivatives to optimize the value of power generation assets.  NextEra Energy Resources provides full energy and capacity requirements services primarily to distribution utilities, which include load-following services and various ancillary services, in certain markets and engages in power and gas marketing and trading activities to take advantage of expected future favorable price movements.

Derivative instruments, when required to be marked to market, are recorded on NextEra Energy's and FPL's consolidated balance sheets as either an asset or liability measured at fair value.  At FPL, substantially all changes in the derivatives' fair value are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the fuel clause or the capacity clause.  For NextEra Energy's non-rate regulated operations, predominantly NextEra Energy Resources, 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 expe nse; and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NextEra Energy's consolidated statements of income.  See Note 3.

53

The changes in the fair value of NextEra Energy's consolidated subsidiaries' energy contract derivative instruments were as follows:

				Hedges on Owned Assets
	Trading			Non- Qualifying			OCI			FPL Cost Recovery Clauses			NextEra Energy Total
	(millions)
Fair value of contracts outstanding at December 31, 2008	$	56		$	143		$	114		$	(1,108	)	$	(795	)
Reclassification to realized at settlement of contracts		(160	)		(208	)		(180	)		1,734			1,186
Effective portion of changes in fair value recorded in OCI		-			-			197			-			197
Ineffective portion of changes in fair value recorded in earnings		-			28			-			-			28
Changes in fair value excluding reclassification to realized		143			163			-			(690	)		(384	)
Fair value of contracts outstanding at December 31, 2009		39			126			131			(64	)		232
Reclassification to realized at settlement of contracts		(98	)		(126	)		(102	)		492			166
Inception value of new contracts		108			(45	)		-			-			63
Effective portion of changes in fair value recorded in OCI		-			-			20			-			20
Ineffective portion of changes in fair value recorded in earnings		-			1			-			-			1
Changes in fair value excluding reclassification to realized		76			457			-			(664	)		(131	)
Fair value of contracts outstanding at December 31, 2010		125			413			49			(236	)		351
Net option premium payments (receipts)		(101	)		9			-			-			(92	)
Net margin cash collateral paid														29
Total mark-to-market energy contract net assets (liabilities) at December 31, 2010	$	24		$	422		$	49		$	(236	)	$	288

NextEra Energy's total mark-to-market energy contract net assets (liabilities) at December 31, 2010 shown above are included in the consolidated balance sheets as follows:

	December 31, 2010
	(millions)
Current derivative assets		$	453
Noncurrent other assets			487
Current derivative liabilities			(468	)
Noncurrent derivative liabilities			(184	)
NextEra Energy's total mark-to-market energy contract net assets		$	288

The sources of fair value estimates and maturity of energy contract derivative instruments at December 31, 2010 were as follows:

	Maturity
	2011			2012			2013			2014			2015		Thereafter			Total
	(millions)
Trading:
Quoted prices in active markets for identical assets	$	8		$	(31	)	$	(42	)	$	-		$	-	$	-		$	(65	)
Significant other observable inputs		(127	)		(30	)		27			2			3		4			(121	)
Significant unobservable inputs		146			40			26			(2	)		-		-			210
Total		27			(21	)		11			-			3		4			24
Owned Assets - Non-Qualifying:
Quoted prices in active markets for identical assets		(27	)		(18	)		(1	)		-			-		-			(46	)
Significant other observable inputs		156			118			29			22			26		38			389
Significant unobservable inputs		26			27			12			7			8		(1	)		79
Total		155			127			40			29			34		37			422
Owned Assets - OCI:
Quoted prices in active markets for identical assets		30			15			-			-			-		-			45
Significant other observable inputs		11			(7	)		-			-			-		-			4
Significant unobservable inputs		-			-			-			-			-		-			-
Total		41			8			-			-			-		-			49
Owned Assets - FPL Cost Recovery Clauses:
Quoted prices in active markets for identical assets		-			-			-			-			-		-			-
Significant other observable inputs		(243	)		-			-			-			-		-			(243	)
Significant unobservable inputs		7			-			-			-			-		-			7
Total		(236	)		-			-			-			-		-			(236	)
Total sources of fair value	$	(13	)	$	114		$	51		$	29		$	37	$	41		$	259

54

Market Risk Sensitivity - Financial instruments and positions affecting the financial statements of NextEra Energy 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.  With respect to certain debt issuances and borrowings, Capital Holdings has entered into three cross currency swaps, two to hedge against currency movements with respect to both interest and principal payments and one to hedge against currency and interest rate movements with respect to both interest and principal payments.  At December 31, 2010 and 2009, the fair value of these cross currency swaps was approximately $44 million and $(1) million, respectively.  Management has established risk management policies to monitor and manage market risks.  With respect to commodities, NextEra Energy's Exposure Management Committee (EMC), which is comprised of certain members of senior management, is responsible for the overall approval of market risk management policies and the delegation of approval and authorization levels.  The EMC receives periodic updates on market positions and related exposures, credit exposures and overall risk management activities.

NextEra Energy 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.  NextEra Energy 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.  NextEra Energy's credit department monitors current and forward credit exposure to counterparties and their affiliates, both on an individual and an aggrega te basis.

Commodity price risk - NextEra Energy uses a value-at-risk (VaR) model to measure 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 December 31, 2010 and 2009, the VaR figures are as follows:

	Trading						Non-Qualifying Hedges and Hedges in OCI and FPL Cost Recovery Clauses(a)						Total
	FPL		NextEra Energy Resources		NextEra Energy		FPL		NextEra Energy Resources		NextEra Energy		FPL		NextEra Energy Resources		NextEra Energy
									(millions)
December 31, 2009	$	-	$	2	$	2	$	61	$	51	$	25	$	61	$	51	$	25
December 31, 2010	$	-	$	3	$	3	$	51	$	21	$	35	$	51	$	23	$	36
Average for the period ended December 31, 2010	$	-	$	4	$	4	$	48	$	32	$	29	$	48	$	34	$	29

¾¾¾¾¾¾¾¾¾¾

(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.

Interest rate risk - NextEra Energy 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.  NextEra Energy and FPL manage their respective interest rate exposure by monitoring current interest rates, entering into interest rate swaps and adjusting their variable rate debt in relation to total capitalization.

The following are estimates of the fair value of NextEra Energy's and FPL's financial instruments:

	December 31, 2010						December 31, 2009
	Carrying Amount			Estimated Fair Value			Carrying Amount			Estimated Fair Value
	(millions)
NextEra Energy:
Fixed income securities:
Special use funds	$	1,701		$	1,701	(a)	$	1,685		$	1,685	(a)
Other investments	$	114		$	114	(a)	$	104		$	104	(a)
Long-term debt, including current maturities	$	19,929		$	20,756	(b)	$	16,869		$	17,256	(b)
Interest rate swaps - net unrealized losses	$	(16	)	$	(16	)(c)	$	(17	)	$	(17	)(c)
FPL:
Fixed income securities - special use funds	$	1,375		$	1,375	(a)	$	1,384		$	1,384	(a)
Long-term debt, including current maturities	$	6,727		$	7,236	(b)	$	5,836		$	6,055	(b)

¾¾¾¾¾¾¾¾¾¾

(a)	Based on quoted market prices for these or similar issues.
(b)	Based on market prices provided by external sources.
(c)	Based on market prices modeled internally.

55

The special use funds of NextEra Energy and FPL consist of restricted funds set aside to cover the cost of storm damage for FPL and for the decommissioning of NextEra Energy's and FPL's nuclear power plants.  A portion of these funds is invested in fixed income debt securities carried at their market value.  At FPL, adjustments to market value result in a corresponding adjustment to the related liability accounts based on current regulatory treatment.  The market value adjustments of NextEra Energy's non-rate regulated operations result in a corresponding adjustment to OCI, except for impairments deemed to be other than temporary 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 m ore 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).

NextEra Energy 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.  At December 31, 2010, the estimated fair value for NextEra Energy'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 - Capital Holdings:
$		300	June 2008	September 2011	Variable	(a)	5.625	%		$	8
$		250	May 2010	November 2013	Variable	(b)	2.55	%			4
$		400	August 2010	September 2015	Variable	(c)	2.60	%			(9	)
Total fair value hedges											3
Cash flow hedges:
	NextEra Energy Resources:
$		43	December 2003	December 2017	4.245	%	Variable	(d)			(3	)
$		14	April 2004	December 2017	3.845	%	Variable	(d)			(1	)
$		150	December 2005	November 2019	4.905	%	Variable	(d)			(14	)
$		384	January 2007	January 2022	5.390	%	Variable	(e)			(42	)
$		83	January 2008	September 2011	3.2050	%	Variable	(d)			(2	)
$		321	January 2009	December 2016	2.680	%	Variable	(d)			(7	)
$		124	January 2009(f)	December 2023	3.725	%	Variable	(d)			3
$		85	January 2009	December 2023	2.578	%	Variable	(g)			3
$		19	March 2009	December 2016	2.655	%	Variable	(d)			-
$		7	March 2009(f)	December 2023	3.960	%	Variable	(d)			-
$		308	May 2009	May 2017	3.015	%	Variable	(d)			(10	)
$		106	May 2009(f)	May 2024	4.663	%	Variable	(d)			1
$		128	December 2009	December 2019	3.830	%	Variable	(d)			(7	)
$		52	December 2009(f)	September 2021	5.500	%	Variable	(d)			-
$		250	April 2010	January 2027	4.040	%	Variable	(e)			(15	)
$		283	October 2010	September 2028	2.822	%	Variable	(d)			15
$		201	December 2010	January 2018	2.313	%	Variable	(e)			(2	)
	Capital Holdings:
$		250	October 2010(f)	June 2021	2.744	%	Variable	(d)			21
$		250	October 2010(f)	September 2021	2.819	%	Variable	(d)			21
$		250	October 2010(f)	June 2023	3.479	%	Variable	(d)			20
Total cash flow hedges											(19	)
Total interest rate swaps										$	(16	)

¾¾¾¾¾¾¾¾¾¾

(a)	Three-month London InterBank Offered Rate (LIBOR) plus 1.18896%.
(b)	Three-month LIBOR plus 0.4726%
(c)	Three-month LIBOR plus 0.7980%
(d)	Three-month LIBOR.
(e)	Six-month LIBOR.
(f)	Exchange of payments does not begin until December 2016, December 2016, May 2017, December 2019, June 2011, September 2011 and June 2013, respectively.
(g)	Three-month Banker's Acceptance Rate.

Based upon a hypothetical 10% decrease in interest rates, which is a reasonable near-term market change, the net fair value of NextEra Energy's net liabilities would increase by approximately $962 million ($385 million for FPL) at December 31, 2010.

56

Equity price risk - Included in the nuclear decommissioning reserve funds of NextEra Energy are marketable equity securities carried at their market value of approximately $2,041 million and $1,705 million ($1,262 million and $1,024 million for FPL) at December 31, 2010 and 2009, respectively.  A hypothetical 10% decrease in the prices quoted by stock exchanges, which is a reasonable near-term market change, would result in a $186 million ($116 million for FPL) reduction in fair value and corresponding adjustments to the related liability accounts based on current regulatory treatment for FPL, or adjustments to OCI for NextEra Energy's non-rate regulated operations, at December 31, 2010.

Credit risk - For all derivative and contractual transactions, NextEra Energy'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.  Relevant considerations when assessing NextEra Energy's energy marketing and trading operations' credit risk exposure include:

·   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 United States.

·   Overall credit risk is managed through established credit policies.

·   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.

·   The use of master netting agreements to offset cash and non-cash gains and losses arising from derivative instruments with the same counterparty.  NextEra Energy's policy is to have master netting agreements in place with significant counterparties.

Based on NextEra Energy's policies and risk exposures related to credit, NextEra Energy and FPL do not anticipate a material adverse effect on their financial positions as a result of counterparty nonperformance.  As of December 31, 2010, approximately 99% of NextEra Energy's and 100% of FPL's energy marketing and trading counterparty credit risk exposure is associated with companies that have investment grade credit ratings.

Item 7A.  Quantitative and Qualitative Disclosures About Market Risk

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

57

Item 8.  Financial Statements and Supplementary Data

MANAGEMENT'S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

NextEra Energy, Inc.'s (NextEra Energy) and Florida Power & Light Company's (FPL) management are responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934.  The consolidated financial statements, which in part are based on informed judgments and estimates made by management, have been prepared in conformity with generally accepted accounting principles applied on a consistent basis.

To aid in carrying out this responsibility, we, along with all other members of management, maintain a system of internal accounting control which is established after weighing the cost of such controls against the benefits derived.  In the opinion of management, the overall system of internal accounting control provides reasonable assurance that the assets of NextEra Energy and FPL and their subsidiaries are safeguarded and that transactions are executed in accordance with management's authorization and are properly recorded for the preparation of financial statements.  In addition, management believes the overall system of internal accounting control provides reasonable assurance that material errors or irregularities would be prevented or detected on a timely basis by employees in the normal course of their duti es.  Any system of internal accounting control, no matter how well designed, has inherent limitations, including the possibility that controls can be circumvented or overridden and misstatements due to error or fraud may occur and not be detected.  Also, because of changes in conditions, internal control effectiveness may vary over time.  Accordingly, even an effective system of internal control will provide only reasonable assurance with respect to financial statement preparation and reporting.

The system of internal accounting control is supported by written policies and guidelines, the selection and training of qualified employees, an organizational structure that provides an appropriate division of responsibility and a program of internal auditing.  NextEra Energy's written policies include a Code of Business Conduct & Ethics that states management's policy on conflicts of interest and ethical conduct.  Compliance with the Code of Business Conduct & Ethics is confirmed annually by key personnel.

The Board of Directors pursues its oversight responsibility for financial reporting and accounting through its Audit Committee.  This Committee, which is comprised entirely of independent directors, meets regularly with management, the internal auditors and the independent auditors to make inquiries as to the manner in which the responsibilities of each are being discharged.  The independent auditors and the internal audit staff have free access to the Committee without management's presence to discuss auditing, internal accounting control and financial reporting matters.

Management assessed the effectiveness of NextEra Energy's and FPL's internal control over financial reporting as of December 31, 2010, using the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission in the Internal Control - Integrated Framework.  Based on this assessment, management believes that NextEra Energy's and FPL's internal control over financial reporting was effective as of December 31, 2010.

NextEra Energy's and FPL's independent registered public accounting firm, Deloitte & Touche LLP, is engaged to express an opinion on NextEra Energy's and FPL's consolidated financial statements and an opinion on NextEra Energy's and FPL's internal control over financial reporting.  Their reports are based on procedures believed by them to provide a reasonable basis to support such opinions.  These reports appear on the following pages.

LEWIS HAY, III	ARMANDO PIMENTEL, JR.
Lewis Hay, III Chairman and Chief Executive Officer of NextEra Energy and Chairman of the Board of FPL	Armando Pimentel, Jr. Executive Vice President, Finance and Chief Financial Officer of NextEra Energy and FPL

ARMANDO J. OLIVERA	CHRIS N. FROGGATT
Armando J. Olivera President and Chief Executive Officer of FPL	Chris N. Froggatt Vice President, Controller and Chief Accounting Officer of NextEra Energy

KIMBERLY OUSDAHL

Kimberly Ousdahl

Vice President, Controller and Chief Accounting Officer of FPL

58

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders

  NextEra Energy, Inc. and Florida Power & Light Company:

We have audited the internal control over financial reporting of NextEra Energy, Inc. and subsidiaries (NextEra Energy) (formerly FPL Group, Inc.) and Florida Power & Light Company and subsidiaries (FPL) as ofDecember 31, 2010, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. NextEra Energy's and FPL’s management are responsible for maintaining effective internal control over financial reporting and for their assessments of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control Over Financial Reporting.  Our responsibility is to express an opinion on NextEra Energy’s and FPL’s internal control over financial reporting based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States).  Those standards require that we plan and perform the audits to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.  Our audits included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinion.

A company's internal control over financial reporting is a process designed by, or under the supervision of, the company's principal executive and principal financial officers, or persons performing similar functions, and effected by the company's board of directors, management, and other personnel 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.  A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded a s necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis.  Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, NextEra Energy and FPL maintained, in all material respects, effective internal control over financial reporting as of December 31, 2010, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements as of and for the year ended December 31, 2010 of NextEra Energy and FPL and our report dated February 25, 2011 expressed an unqualified opinion on those financial statements.

DELOITTE & TOUCHE LLP

Certified Public Accountants

Miami, Florida

February 25, 2011

59

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders

  NextEra Energy, Inc. and Florida Power & Light Company:

We have audited the accompanying consolidated balance sheets of NextEra Energy, Inc. and subsidiaries (NextEra Energy) (formerly FPL Group, Inc.) and the separate consolidated balance sheets of Florida Power & Light Company and subsidiaries (FPL) as of December 31, 2010 and 2009, and the related consolidated statements of income, NextEra Energy’s common shareholders' equity, FPL’s common shareholder’s equity and cash flows for each of the three years in the period ended December 31, 2010.  These financial statements are the responsibility of the respective company's management.  Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States).  Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement.  An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements.  An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation.  We believe that our audits provide a reasonable basis for our opinion.

In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of NextEra Energy and FPL at December 31, 2010 and 2009, and the respective results of their operations and their cash flows for each of the three years in the period ended December 31, 2010, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), NextEra Energy’s and FPL’s internal control over financial reporting as of December 31, 2010, based on the criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 25, 2011 expressed an unqualified opinion on NextEra Energy’s and FPL’s internal control over financial reporting.

DELOITTE & TOUCHE LLP

Certified Public Accountants

Miami, Florida

February 25, 2011

60

NEXTERA ENERGY, INC.

CONSOLIDATED STATEMENTS OF INCOME

(millions, except per share amounts)

	Years Ended December 31,
	2010			2009			2008
OPERATING REVENUES	$	15,317		$	15,643		$	16,410
OPERATING EXPENSES
Fuel, purchased power and interchange		6,242			7,405			8,412
Other operations and maintenance		2,877			2,649			2,527
Depreciation and amortization		1,807			1,765			1,442
Taxes other than income taxes and other		1,148			1,230			1,204
Total operating expenses		12,074			13,049			13,585
OPERATING INCOME		3,243			2,594			2,825
OTHER INCOME (DEDUCTIONS)
Interest expense		(979	)		(849	)		(813	)
Equity in earnings of equity method investees		58			52			93
Allowance for equity funds used during construction		37			53			35
Interest income		91			78			72
Gains on disposal of assets - net		67			60			18
Other than temporary impairment losses on securities held in nuclear decommissioning funds		(16	)		(58	)		(148	)
Other - net		(12	)		12			7
Total other deductions - net		(754	)		(652	)		(736	)
INCOME BEFORE INCOME TAXES		2,489			1,942			2,089
INCOME TAXES		532			327			450
NET INCOME	$	1,957		$	1,615		$	1,639
Earnings per share of common stock:
Basic	$	4.77		$	3.99		$	4.10
Assuming dilution	$	4.74		$	3.97		$	4.07
Dividends per share of common stock	$	2.00		$	1.89		$	1.78
Weighted-average number of common shares outstanding:
Basic		410.3			404.4			400.1
Assuming dilution		413.0			407.2			402.7

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

61

NEXTERA ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(millions)

	December 31,
	2010			2009
PROPERTY, PLANT AND EQUIPMENT
Electric utility plant in service and other property	$	48,841		$	46,330
Nuclear fuel		1,539			1,414
Construction work in progress		3,841			2,425
Less accumulated depreciation and amortization		(15,146	)		(14,091	)
Total property, plant and equipment - net ($2,398 related to VIEs at December 31, 2010)		39,075			36,078
CURRENT ASSETS
Cash and cash equivalents		302			238
Customer receivables, net of allowances of $20 and $23, respectively		1,509			1,431
Other receivables, net of allowances of $1 and $1, respectively		1,073			816
Materials, supplies and fossil fuel inventory		857			877
Regulatory assets:
Deferred clause and franchise expenses		368			69
Derivatives		236			68
Other		82			72
Derivatives		506			357
Other		325			409
Total current assets		5,258			4,337
OTHER ASSETS
Special use funds		3,742			3,390
Other investments		971			935
Prepaid benefit costs		1,259			1,184
Regulatory assets:
Securitized storm-recovery costs ($356 related to a VIE at December 31, 2010)		581			644
Other		329			265
Other		1,779			1,625
Total other assets		8,661			8,043
TOTAL ASSETS	$	52,994		$	48,458
CAPITALIZATION
Common stock	$	4		$	4
Additional paid-in capital		5,418			5,055
Retained earnings		8,873			7,739
Accumulated other comprehensive income		166			169
Total common shareholders' equity		14,461			12,967
Long-term debt ($1,338 related to VIEs at December 31, 2010)		18,013			16,300
Total capitalization		32,474			29,267
CURRENT LIABILITIES
Commercial paper		889			2,020
Current maturities of long-term debt		1,920			569
Accounts payable		1,124			992
Customer deposits		634			613
Accrued interest and taxes		462			466
Regulatory liabilities:
Deferred clause and franchise revenues		47			377
Other		4			2
Derivatives		536			221
Accrued construction-related expenditures		371			476
Other		917			713
Total current liabilities		6,904			6,449
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations		1,639			2,418
Accumulated deferred income taxes		5,109			4,860
Regulatory liabilities:
Accrued asset removal costs		2,244			2,251
Asset retirement obligation regulatory expense difference		1,592			671
Other		423			260
Derivatives		243			170
Deferral related to differential membership interests ($949 related to VIEs at December 31, 2010)		949			700
Other		1,417			1,412
Total other liabilities and deferred credits		13,616			12,742
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	52,994		$	48,458

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

62

NEXTERA ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(millions)

	Years Ended December 31,
	2010			2009			2008
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	1,957		$	1,615		$	1,639
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization		1,807			1,765			1,442
Nuclear fuel amortization		285			239			201
Unrealized (gains) losses on marked to market energy contracts		(386	)		59			(337	)
Deferred income taxes		511			273			569
Cost recovery clauses and franchise fees		(629	)		624			(111	)
Changes in prepaid option premiums and derivative settlements		86			(11	)		(12	)
Equity in earnings of equity method investees		(58	)		(52	)		(93	)
Distributions of earnings from equity method investees		74			69			124
Allowance for equity funds used during construction		(37	)		(53	)		(35	)
Gains on disposal of assets - net		(67	)		(60	)		(18	)
Other than temporary impairment losses on securities held in nuclear decommissioning funds		16			58			148
Changes in operating assets and liabilities:
Customer receivables		(73	)		18			49
Other receivables		(29	)		(13	)		(26	)
Materials, supplies and fossil fuel inventory		22			85			(106	)
Other current assets		(52	)		9			(31	)
Other assets		42			(103	)		(166	)
Accounts payable		179			(86	)		(120	)
Customer deposits		21			38			37
Margin cash collateral		61			(110	)		49
Income taxes		56			8			(17	)
Interest and other taxes		(3	)		22			30
Other current liabilities		76			(45	)		189
Other liabilities		(63	)		(5	)		(61	)
Other - net		38			119			59
Net cash provided by operating activities		3,834			4,463			3,403
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures of FPL		(2,605	)		(2,522	)		(2,234	)
Independent power and other investments of NextEra Energy Resources		(2,899	)		(3,068	)		(2,715	)
Cash grants under the American Recovery and Reinvestment Act of 2009		588			100			-
Funds received from a spent fuel settlement		44			86			-
Nuclear fuel purchases		(274	)		(362	)		(247	)
Other capital expenditures		(68	)		(54	)		(40	)
Proceeds from sale of securities in special use funds		6,726			4,592			2,235
Purchases of securities in special use funds		(6,835	)		(4,710	)		(2,315	)
Proceeds from sale of other securities		721			773			28
Purchases of other securities		(714	)		(782	)		(84	)
Funding of loan		-			-			(500	)
Other - net		32			12			64
Net cash used in investing activities		(5,284	)		(5,935	)		(5,808	)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt		3,724			3,220			3,827
Retirements of long-term debt		(769	)		(1,635	)		(1,358	)
Proceeds from sale of differential membership interests		261			-			-
Net change in short-term debt		(1,130	)		154			848
Issuances of common stock - net		308			198			41
Dividends on common stock		(823	)		(766	)		(714	)
Other - net		(57	)		4			6
Net cash provided by financing activities		1,514			1,175			2,650
Net increase (decrease) in cash and cash equivalents		64			(297	)		245
Cash and cash equivalents at beginning of year		238			535			290
Cash and cash equivalents at end of year	$	302		$	238		$	535
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)	$	916		$	805		$	764
Cash paid for income taxes - net	$	20		$	61		$	4
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Assumption of debt in connection with the purchase of independent power projects	$	35		$	-		$	31
Accrued property additions	$	545		$	683		$	448

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

63

NEXTERA ENERGY, INC.

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY

(millions)

	Common Stock(a)				Additional Paid-In Capital			Unearned ESOP Compensation				Accumulated Other Comprehensive Income (Loss)(b)				Retained Earnings			Common Shareholders' Equity
	Shares		Aggregate Par Value
Balances, December 31, 2007	407		$	4	$	4,784			$	(114	)		$	116		$	5,945			$	10,735
Net income	-			-		-				-				-			1,639
Issuances of common stock, net of issuance cost of less than $1	1			-		38				4				-			-
Exercise of stock options and other incentive plan activity	1			-		53				-				-			-
Dividends on common stock	-			-		-				-				-			(714	)
Earned compensation under ESOP	-			-		30				10				-			-
Other comprehensive income	-			-		-				-				40			-
Defined benefit pension and other benefits plans	-			-		-				-				(167	)		-
Implementation of new accounting rules	-			-		-				-				(2	)		15
Balances, December 31, 2008	409	(c)		4		4,905				(100	)			(13	)		6,885			$	11,681
Net income	-			-		-				-				-			1,615
Issuances of common stock, net of issuance cost of approximately $2	4			-		204				4				-			-
Exercise of stock options and other incentive plan activity	1			-		56				-				-			-
Dividends on common stock	-			-		-				-				-			(766	)
Earned compensation under ESOP	-			-		30				11				-			-
Other comprehensive income	-			-		-				-				165			-
Defined benefit pension and other benefits plans	-			-		-				-				22			-
Premium on publicly-traded equity units known as Corporate Units	-			-		(47	)			-				-			-
Unamortized issuance costs on publicly-traded equity units known as Corporate Units	-			-		(8	)			-				-			-
Implementation of new accounting rules	-			-		-				-				(5	)		5
Balances, December 31, 2009	414	(c)		4		5,140				(85	)			169			7,739			$	12,967
Net income	-			-		-				-				-			1,957
Issuances of common stock, net of issuance cost of approximately $2	6			-		279				5				-			-
Exercise of stock options and other incentive plan activity	1			-		107				-				-			-
Dividends on common stock	-			-		-				-				-			(823	)
Earned compensation under ESOP	-			-		26				11				-			-
Other comprehensive loss	-			-		-				-				(5	)		-
Defined benefit pension and other benefits plans	-			-		-				-				2			-
Premium on publicly-traded equity units known as Corporate Units	-			-		(59	)			-				-			-
Unamortized issuance costs on publicly-traded equity units known as Corporate Units	-			-		(6	)			-				-			-
Balances, December 31, 2010	421	(c)	$	4	$	5,487			$	(69	)		$	166		$	8,873			$	14,461

¾¾¾¾¾¾¾¾¾¾

(a)	$0.01 par value, authorized - 800,000,000 shares; outstanding shares 420,861,536, 413,622,436 and 408,915,305 at December 31, 2010, 2009 and 2008, respectively.
(b)	Comprehensive income, which includes net income and other comprehensive income (loss), totaled approximately $1,954 million, $1,802 million and $1,512 million for 2010, 2009 and 2008, respectively.
(c)	Outstanding and unallocated shares held by the Employee Stock Ownership Plan (ESOP) Trust totaled approximately 5 million, 6 million and 7 million at December 31, 2010, 2009 and 2008, respectively; the original number of shares purchased and held by the ESOP Trust was approximately 25 million shares.

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

64

FLORIDA POWER & LIGHT COMPANY

CONSOLIDATED STATEMENTS OF INCOME

(millions)

	Years Ended December 31,
	2010			2009			2008
OPERATING REVENUES	$	10,485		$	11,491		$	11,649
OPERATING EXPENSES
Fuel, purchased power and interchange		4,982			6,220			6,749
Other operations and maintenance		1,620			1,496			1,438
Depreciation and amortization		1,008			1,097			860
Taxes other than income taxes and other		1,026			1,097			1,073
Total operating expenses		8,636			9,910			10,120
OPERATING INCOME		1,849			1,581			1,529
OTHER INCOME (DEDUCTIONS)
Interest expense		(361	)		(318	)		(334	)
Allowance for equity funds used during construction		36			53			35
Other - net		1			(12	)		2
Total other deductions - net		(324	)		(277	)		(297	)
INCOME BEFORE INCOME TAXES		1,525			1,304			1,232
INCOME TAXES		580			473			443
NET INCOME	$	945		$	831		$	789

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

65

FLORIDA POWER & LIGHT COMPANY

CONSOLIDATED BALANCE SHEETS

(millions)

	December 31,
	2010			2009
ELECTRIC UTILITY PLANT
Plant in service	$	29,519		$	28,677
Nuclear fuel		729			756
Construction work in progress		2,175			1,549
Less accumulated depreciation and amortization		(10,871	)		(10,578	)
Electric utility plant - net		21,552			20,404
CURRENT ASSETS
Cash and cash equivalents		20			83
Customer receivables, net of allowances of $17 and $21, respectively		710			838
Other receivables, net of allowances of $1 and $1, respectively		395			182
Materials, supplies and fossil fuel inventory		505			529
Regulatory assets:
Deferred clause and franchise expenses		368			69
Derivatives		236			68
Other		76			69
Other		145			123
Total current assets		2,455			1,961
OTHER ASSETS
Special use funds		2,637			2,408
Prepaid benefit costs		1,035			1,017
Regulatory assets:
Securitized storm-recovery costs ($356 related to a VIE at December 31, 2010)		581			644
Other		293			214
Other		145			164
Total other assets		4,691			4,447
TOTAL ASSETS	$	28,698		$	26,812
CAPITALIZATION
Common stock	$	1,373		$	1,373
Additional paid-in capital		5,054			4,393
Retained earnings		3,364			2,670
Total common shareholder's equity		9,791			8,436
Long-term debt ($486 related to a VIE at December 31, 2010)		6,682			5,794
Total capitalization		16,473			14,230
CURRENT LIABILITIES
Commercial paper		101			818
Current maturities of long-term debt		45			42
Accounts payable		554			539
Customer deposits		628			607
Accrued interest and taxes		311			303
Regulatory liabilities - deferred clause and franchise revenues		47			377
Derivatives		245			77
Accrued construction-related expenditures		183			296
Other		394			363
Total current liabilities		2,508			3,422
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations		1,083			1,833
Accumulated deferred income taxes		3,835			3,509
Regulatory liabilities:
Accrued asset removal costs		2,244			2,251
Asset retirement obligation regulatory expense difference		1,592			671
Other		377			244
Other		586			652
Total other liabilities and deferred credits		9,717			9,160
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	28,698		$	26,812

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

66

FLORIDA POWER & LIGHT COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(millions)

	Years Ended December 31,
	2010			2009			2008
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	945		$	831		$	789
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization		1,008			1,097			860
Nuclear fuel amortization		137			127			106
Deferred income taxes		419			391			307
Cost recovery clauses and franchise fees		(629	)		624			(111	)
Allowance for equity funds used during construction		(36	)		(53	)		(35	)
Changes in operating assets and liabilities:
Customer receivables		127			(42	)		11
Other receivables		(43	)		42			(11	)
Materials, supplies and fossil fuel inventory		23			34			20
Other current assets		(25	)		6			(19	)
Other assets		40			(62	)		(96	)
Accounts payable		51			(91	)		(71	)
Customer deposits		22			37			39
Income taxes		(129	)		(132	)		175
Interest and other taxes		7			10			9
Other current liabilities		22			(33	)		138
Other liabilities		(21	)		10			(19	)
Other - net		16			75			88
Net cash provided by operating activities		1,934			2,871			2,180
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures		(2,605	)		(2,522	)		(2,234	)
Cash grants under the American Recovery and Reinvestment Act of 2009		161			-			-
Funds received from a spent fuel settlement		32			71			-
Nuclear fuel purchases		(101	)		(195	)		(133	)
Proceeds from sale of securities in special use funds		5,079			3,270			1,454
Purchases of securities in special use funds		(5,160	)		(3,349	)		(1,512	)
Other - net		33			(1	)		(2	)
Net cash used in investing activities		(2,561	)		(2,726	)		(2,427	)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt		924			516			589
Retirements of long-term debt		(42	)		(263	)		(241	)
Net change in short-term debt		(717	)		45			(69	)
Capital contribution from NextEra Energy		660			-			75
Dividends		(250	)		(485	)		(50	)
Other - net		(11	)		5			-
Net cash provided by (used in) financing activities		564			(182	)		304
Net increase (decrease) in cash and cash equivalents		(63	)		(37	)		57
Cash and cash equivalents at beginning of year		83			120			63
Cash and cash equivalents at end of year	$	20		$	83		$	120
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest (net of amount capitalized)	$	321		$	305		$	320
Cash paid (received) for income taxes - net	$	291		$	232		$	(11	)
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued property additions	$	275		$	418		$	315

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

67

FLORIDA POWER & LIGHT COMPANY

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDER'S EQUITY(a)

(millions)

	Common Stock(b)		Additional Paid-In Capital			Retained Earnings			Common Shareholder's Equity
Balances, December 31, 2007	$	1,373		$	4,318	$	1,584			$	7,275
Net income		-			-		789
Capital contributions from NextEra Energy		-			75		-
Dividends to NextEra Energy		-			-		(50	)
Balances, December 31, 2008		1,373			4,393		2,323			$	8,089
Net income		-			-		831
Dividends to NextEra Energy		-			-		(485	)
Other		-			-		1
Balances, December 31, 2009		1,373			4,393		2,670			$	8,436
Net income		-			-		945
Capital contributions from NextEra Energy		-			660		-
Dividends to NextEra Energy		-			-		(250	)
Other		-			1		(1	)
Balances, December 31, 2010	$	1,373		$	5,054	$	3,364			$	9,791

¾¾¾¾¾¾¾¾¾¾

(a)	FPL's comprehensive income is the same as reported net income.
(b)	No par value, 1,000 shares authorized, issued and outstanding.

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

68

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Years Ended December 31, 2010, 2009 and 2008

1.  Summary of Significant Accounting and Reporting Policies

Basis of Presentation - The operations of NextEra Energy, Inc. (NextEra Energy), formerly known as FPL Group, Inc., are conducted primarily through its wholly-owned subsidiary Florida Power & Light Company (FPL) and its wholly-owned indirect subsidiary NextEra Energy Resources, LLC (NextEra Energy Resources).  FPL, a rate-regulated public utility, supplies electric service to approximately 4.5 million customer accounts throughout most of the east and lower west coasts of Florida.  NextEra Energy Resources invests in independent power projects through both controlled and consolidated entities and non-controlling ownership interests in joint ventures essentially all of which are accounted for under the equity method.

The consolidated financial statements of NextEra Energy and FPL include the accounts of their respective majority-owned and controlled subsidiaries.  All significant intercompany balances and transactions have been eliminated in consolidation.  Certain amounts included in prior years' consolidated financial statements have been reclassified to conform to the current year's presentation.  See Note 15 for a discussion of a change in allocation of certain costs.  The preparation of financial statements requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities.  Actual results could differ from those estimates.

Regulation - FPL is subject to regulation by the Florida Public Service Commission (FPSC) and the Federal Energy Regulatory Commission (FERC).  Its rates are designed to recover the cost of providing electric service to its customers including a reasonable rate of return on invested capital.  As a result of this cost-based regulation, FPL follows the accounting guidance that allows regulators to create assets and impose liabilities that would not be recorded by non-rate regulated entities.  Regulatory assets and liabilities represent probable future revenues that will be recovered from or refunded to customers through the ratemaking process.

Cost recovery clauses, which are designed to permit full recovery of certain costs and provide a return on certain assets allowed to be recovered through the various clauses, include substantially all fuel, purchased power and interchange expenses, conservation and certain environmental-related expenses, certain revenue taxes and franchise fees.  Beginning in 2009, pre-construction costs and carrying charges for FPL's two additional nuclear units at Turkey Point and carrying charges on construction costs for FPL's approximately 400 megawatt (mw) to 460 mw of additional capacity at St. Lucie and Turkey Point are also recovered through a cost recovery clause.  Also beginning in 2009, costs incurred for FPL's three solar generating facilities are recovered through a cost recovery clause.  Once the new combin ed-cycle natural gas unit at FPL's West County Energy Center (WCEC) Unit No. 3 is placed into service, the incremental cost associated with the new unit up to the amount of the projected fuel savings for customers during the 2010 rate agreement will also be recovered through a cost recovery clause and recorded as retail base revenues.  See Revenues and Rates below.  Revenues from cost recovery clauses are recorded when billed; FPL achieves matching of costs and related revenues by deferring the net underrecovery or overrecovery.  Any underrecovered costs or overrecovered revenues are collected from or returned to customers in subsequent periods.

If FPL were no longer subject to cost-based rate regulation, the existing regulatory assets and liabilities would be written off unless regulators specify an alternative means of recovery or refund.  In addition, the FPSC has the authority to disallow recovery of costs that it considers excessive or imprudently incurred.  The continued applicability of regulatory accounting is assessed at each reporting period.

Revenues and Rates - FPL's retail and wholesale utility rate schedules are approved by the FPSC and the FERC, respectively.  FPL records unbilled base revenues for the estimated amount of energy delivered to customers but not yet billed.  Unbilled base revenues are included in customer receivables and amounted to approximately $148 million and $121 million at December 31, 2010 and 2009, respectively.  FPL's operating revenues also include amounts resulting from cost recovery clauses (see Regulation), franchise fees, gross receipts taxes and surcharges related to storm-recovery bonds (see Note 9 - FPL).  Franchise fees and gross receipts taxes are imposed on FPL; however, the FPSC allows FPL to include in the amounts charged to custome rs the amount of the gross receipts tax for all customers and the franchise amount for those customers located in the jurisdiction that imposes the fee.  Accordingly, franchise fees and gross receipts taxes are reported gross in operating revenues and taxes other than income taxes and other on NextEra Energy's and FPL's consolidated statements of income and were approximately $687 million, $791 million and $781 million in 2010, 2009 and 2008, respectively.  The revenues from the surcharges related to storm-recovery bonds included in operating revenues on NextEra Energy's and FPL's consolidated statements of income were approximately $101 million, $91 million and $97 million in 2010, 2009 and 2008, respectively.  FPL also collects municipal utility taxes which are reported gross in customer receivables and accounts payable on NextEra Energy's and FPL's consolidated balance sheets.

69

Effective March 1, 2010, pursuant to an FPSC final order (FPSC rate order) with regard to FPL’s March 2009 petition (2009 rate case) that requested, among other things, a permanent base rate increase, new retail base rates for FPL were established, resulting in an increase in retail base revenues of approximately $75 million on an annualized basis.  The FPSC rate order also established a regulatory return on common equity (ROE) of 10.0% with a range of plus or minus 100 basis points and an adjusted regulatory equity ratio of 59.1%, and shifted certain costs from retail base rates to the capacity clause.  In addition, the FPSC rate order directed FPL to reduce depreciation expense (surplus depreciation credit) over the 2010 to 2013 period related to a depreciation reserve surplus of approximately $895 mil lion.  Subsequently, the principal parties in FPL’s 2009 rate case signed a stipulation and settlement regarding FPL’s base rates (2010 rate agreement) and, on February 1, 2011, the FPSC issued a final order reflecting its decision to approve the 2010 rate agreement.  Key elements of the 2010 rate agreement, which will be effective through December 31, 2012, are as follows:

· Subject to the provisions of the 2010 rate agreement, retail base rates will be effectively frozen through the end of 2012.

· Incremental cost recovery through FPL’s capacity cost recovery clause (capacity clause) for WCEC Unit No. 3, which is expected to be placed in service by mid-2011, will be permitted up to the amount of the projected fuel savings for customers during the term of the 2010 rate agreement.

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

· If FPL's earned regulatory ROE falls below 9%, FPL may seek retail base rate relief.  If FPL's earned regulatory ROE rises above 11%, any party to the 2010 rate agreement may seek a reduction in FPL’s retail base rates.  In determining the regulatory ROE for all purposes under the 2010 rate agreement, earnings will be calculated on an actual, non-weather-adjusted basis.

· FPL can vary the amount of surplus depreciation credit taken in any calendar year up to a cap in 2010 of $267 million, a cap in subsequent years of $267 million plus the amount of any unused portion from prior years, and a cap of $776 million (surplus depreciation credit cap) over the course of the 2010 rate agreement, provided that in any year of the 2010 rate agreement, including 2010, FPL must use at least enough surplus depreciation credit to maintain a 9% earned regulatory ROE but may not use any amount of surplus depreciation credit that would result in an earned regulatory ROE in excess of 11%.

NextEra Energy’s and FPL’s financial statements contained herein reflect the effects of the FPSC rate order and the 2010 rate agreement.

Under the terms of a rate agreement approved in 2005 (2005 rate agreement), which was in effect from January 1, 2006 through February 28, 2010, retail base rates did not increase except to allow recovery of the revenue requirements of FPL's three power plants that achieved commercial operation during the term of the 2005 rate agreement:  Turkey Point Unit No. 5 in 2007 and WCEC Units Nos. 1 and 2 in 2009.  Under the terms of the 2005 rate agreement, FPL's electric property depreciation rates were based upon the comprehensive depreciation studies it filed with the FPSC in March 2005; however, FPL reduced depreciation on its plant in service by $125 million each year as allowed by the 2005 rate agreement.  The 2005 rate agreement also provided for a revenue sharing mechanism, whereby revenues from retail base operations in excess of certain thresholds would be shared with customers.  During the term of the 2005 rate agreement, FPL's revenues did not exceed the thresholds.

NextEra Energy Resources' revenue is recorded on the basis of commodities delivered, contracts settled or services rendered, and includes estimated amounts yet to be billed to customers.  Certain commodity contracts for the purchase and sale of power that meet the definition of a derivative are recorded at fair value with subsequent changes in fair value recognized as revenue, unless hedge accounting is applied.  See Energy Trading and Note 3.

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Electric Plant, Depreciation and Amortization - The cost of additions to units of property of FPL and NextEra Energy Resources is added to electric utility plant.  In accordance with regulatory accounting, the cost of FPL's units of utility property retired, less estimated net salvage value, is charged to accumulated depreciation.  Maintenance and repairs of property as well as replacements and renewals of items determined to be less than units of utility property are charged to other operations and maintenance (O&M) expenses.  At December 31, 2010, the electric generating, transmission, distribution and general facilities of FPL represented approximately 47%, 12%, 37% and 4%, respectively, of FPL's gross investment in electric utility plan t in service.  Substantially all of FPL's properties are subject to the lien of FPL's mortgage, which secures most debt securities issued by FPL.  A number of NextEra Energy Resources' generating facilities are encumbered by liens securing various financings.  The net book value of NextEra Energy Resources' assets serving as collateral was approximately $8 billion at December 31, 2010.  The American Recovery and Reinvestment Act of 2009, as amended (Recovery Act) provided for an option to elect a cash grant (convertible ITCs) for certain renewable energy property (renewable property).  Convertible ITCs are recorded as a reduction in property, plant and equipment on NextEra Energy's and FPL's consolidated balance sheets and are amortized as a reduction to depreciation and amortization expense over the estimated life of the related property.  During 2010 and 2009, NextEra Energy recorded convertible ITCs of approximately $1 billion ($186 million at FPL) and $517 million ($44 million at FPL), respectively, of which $429 million ($124 million at FPL) and $417 million ($44 million at FPL) are included in other receivables on NextEra Energy's and FPL's consolidated balance sheets at December 31, 2010 and 2009, respectively.

Depreciation of FPL's electric property is primarily provided on a straight-line average remaining life basis.  FPL includes in depreciation expense a provision for fossil plant dismantlement, nuclear plant decommissioning (see Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs) and amortization of pre-construction costs associated with planned nuclear units recovered through a cost recovery clause.  For substantially all of FPL's property, depreciation studies are performed and filed with the FPSC at least every four years.  As part of the FPSC rate order, the FPSC approved new depreciation rates which became effective January 1, 2010.  In addition, in accordance with the 2010 rate agreement, FPL can vary the amount of surplus depreciation cred it taken in any calendar year up to a maximum of $267 million (with any unused portion of the maximum rolling over to and available in subsequent years), provided its regulatory ROE remains within the range of 9% to 11%; FPL may use up to a maximum of $776 million in surplus depreciation credit over the course of the 2010 rate agreement.  As of December 31, 2010, approximately $772 million of the surplus depreciation credit cap remains.  Under the terms of the 2005 rate agreement, FPL's electric property depreciation rates were based upon the comprehensive depreciation studies it filed with the FPSC in March 2005; however FPL reduced depreciation by $125 million annually as was allowed by the 2005 rate agreement.  The weighted annual composite depreciation rate for FPL's electric plant in service, including capitalized software, but excluding the effects of decommissioning, dismantlement and the depreciation adjustments discussed above, was approximately 3.2% for 2010 and 3 .6% for both 2009 and 2008.  NextEra Energy Resources' electric plants in service less salvage value, if any, are depreciated primarily using the straight-line method over their estimated useful lives.  NextEra Energy Resources' effective depreciation rates, excluding decommissioning, were 4.4%, 4.2% and 4.3% for 2010, 2009 and 2008, respectively.

Nuclear Fuel - FPL and NextEra Energy Resources have several contracts for the supply of uranium, conversion, enrichment and fabrication of nuclear fuel.  See Note 14 - Contracts.  FPL's and NextEra Energy Resources' nuclear fuel costs are charged to fuel expense on a unit of production method.  See Note 9 - FPL regarding the leasing of nuclear fuel from a consolidated variable interest entity (VIE) by FPL prior to March 2010.

Construction Activity - Allowance for funds used during construction (AFUDC) is a non-cash item which represents the allowed cost of capital, including an ROE, used to finance FPL construction projects.  The portion of AFUDC attributable to borrowed funds is recorded as a reduction of interest expense and the remainder is recorded as other income.  FPSC rules limit the recording of AFUDC to projects that cost in excess of 0.5% of a utility's plant in service balance and require more than one year to complete.  FPSC rules allow construction projects below the 0.5% threshold as a component of rate base.  During the period January 2010 through March 2010 and during April 2010 through December 2010, AFUDC was capitalized at a rate of 7.41% and 6.41%, respectively, and amounted to approximately $50 million for the year.  During 2009 and 2008, AFUDC was capitalized at a rate of 7.41% and 7.65%, respectively, and amounted to approximately $74 million and $53 million, respectively.  See Note 14 - Commitments.

FPL's construction work in progress includes construction materials, progress payments on major equipment contracts, third-party engineering costs, AFUDC and other costs directly associated with the construction of various projects.  Upon completion of the projects, these costs are transferred to electric utility plant in service.  Capitalized costs associated with construction activities are charged to O&M expenses when recoverability is no longer probable.  See Regulation above for information on recovery of costs associated with new nuclear capacity and solar generating facilities.

NextEra Energy Resources capitalizes project development costs once it is probable that such costs will be realized through the ultimate construction of a power plant or sale of development rights.  At December 31, 2010 and 2009, NextEra Energy Resources' capitalized development costs totaled approximately $99 million and $56 million, respectively, which are included in other assets on NextEra Energy's consolidated balance sheets.  These costs include land rights and other third-party costs directly associated with the development of a new project.  Upon commencement of construction, these costs either are transferred to construction work in progress or remain in other assets, depending upon the nature of the cost.  Capitalized development costs are charged to O&M expenses when recovera bility is no longer probable.

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NextEra Energy Resources' construction work in progress includes construction materials, prepayments on turbine generators and other equipment, third-party engineering costs, capitalized interest and other costs directly associated with the construction and development of the project.  Interest capitalized on construction projects amounted to approximately $71 million, $85 million and $55 million during 2010, 2009 and 2008, respectively.  Interest expense allocated from NextEra Energy Capital Holdings, Inc. (Capital Holdings), formerly known as FPL Group Capital Inc, to NextEra Energy Resources is based on a deemed capital structure of 70% debt.  Upon commencement of plant operation, costs associated with construction work in progress are transferred to electric utility plant in service and other property .

Asset Retirement Obligations - NextEra Energy and FPL each account for asset retirement obligations and conditional asset retirement obligations (collectively, AROs) under accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated, with the offsetting associated asset retirement costs capitalized as part of the carrying amount of the long-lived assets.  The asset retirement cost is subsequently allocated to expense using a systematic and rational method over the asset’s estimated useful life.  Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense, which is included in depreciation and amortization expense in the consolidated statements of income.  Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the asset retirement cost and ARO and regulatory liability, in the case of FPL.  See Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below and Note 13.

Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs - For ratemaking purposes, FPL accrues for the cost of end of life retirement and disposal of its nuclear, fossil and solar plants over the expected service life of each unit based on nuclear decommissioning and fossil and solar dismantlement studies periodically filed with the FPSC.  In addition, FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC.  As approved by the FPSC, FPL previously suspended its annual decommissioning accrual.  For financial reporting purposes, FPL recognizes decommissioning and dismantlement liabilities in accordance with accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred.  Any differences between expense recognized for financial reporting purposes and the amount recoverable through rates are reported as a regulatory liability in accordance with regulatory accounting.  See Electric Plant, Depreciation and Amortization, Asset Retirement Obligations and Note 13.

Nuclear decommissioning studies are performed at least every five years and are submitted to the FPSC for approval.  FPL filed updated nuclear decommissioning studies with the FPSC in December 2010.  These studies reflect FPL's current plans, under the operating licenses, for prompt dismantlement of Turkey Point Units Nos. 3 and 4 following the end of plant operation with decommissioning activities commencing in 2032 and 2033, respectively, and provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the prompt dismantlement of St. Lucie Unit No. 2 at the end of its useful life in 2043.  These studies also assume that FPL will be storing spent fuel on site pending removal to a U.S. government facility.  The studies indica te FPL's portion of the ultimate costs of decommissioning its four nuclear units, including costs associated with spent fuel storage above what is expected to be refunded by the U.S. Department of Energy (DOE) under a spent fuel settlement agreement, to be approximately $6.2 billion.  FPL's portion of the ultimate cost of decommissioning its four units, expressed in 2010 dollars, is estimated by the studies to aggregate $2.3 billion.

Restricted funds for the payment of future expenditures to decommission FPL's nuclear units are included in nuclear decommissioning reserve funds, which are included in special use funds on NextEra Energy's and FPL's consolidated balance sheets.  Marketable securities held in the decommissioning funds are classified as available for sale and are carried at fair value with market adjustments, including any other than temporary impairment losses, resulting in a corresponding adjustment to the related regulatory liability accounts consistent with regulatory treatment.  See Note 5.  Contributions to the funds have been suspended since 2005.  Fund earnings, net of taxes, are reinvested in the funds.  Earnings are recognized as income/loss and an offset is recorded to reflect a correspo nding increase/decrease in the related regulatory liability accounts.  As a result, there is no effect on net income.  During 2010, 2009 and 2008, fund earnings on decommissioning funds were approximately $76 million, $81 million and $63 million, respectively.  The tax effects of amounts not yet recognized for tax purposes are included in accumulated deferred income taxes.

Fossil and solar plant dismantlement studies are performed at least every four years and are submitted to the FPSC for approval.  FPL's latest fossil and solar plant dismantlement studies became effective January 1, 2010 and resulted in an increase in the annual expense from $15 million to $18 million which is recorded in depreciation and amortization expense in NextEra Energy's and FPL's consolidated statements of income.  At December 31, 2010, FPL's portion of the ultimate cost to dismantle its fossil and solar units is approximately $860 million, or $455 million expressed in 2010 dollars.

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NextEra Energy Resources records nuclear decommissioning liabilities for Seabrook Station (Seabrook), Duane Arnold Energy Center (Duane Arnold) and Point Beach Nuclear Power Plant (Point Beach) in accordance with accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred.  The liability is being accreted using the interest method through the date decommissioning activities are expected to be complete.  See Note 13.  At December 31, 2010 and 2009, NextEra Energy Resources' ARO related to nuclear decommissioning totaled approximately $478 million and $518 million, respectively, and was determined using various internal and external data and applying a probability percentage to a variety of scenarios regarding the life of the pl ant and timing of decommissioning.  NextEra Energy Resources' portion of the ultimate cost of decommissioning its nuclear plants, including costs associated with spent fuel storage above what is expected to be refunded by the DOE under a spent fuel settlement agreement, is estimated to be approximately $9.5 billion, or $1.8 billion expressed in 2010 dollars.

Seabrook's decommissioning funding plan is based on a comprehensive nuclear decommissioning study filed with the New Hampshire Nuclear Decommissioning Financing Committee (NDFC) in 2007 and is effective for four years.  Currently, there are no ongoing decommissioning funding requirements for Duane Arnold and Point Beach, however, the U.S. Nuclear Regulatory Commission (NRC) has the authority to require additional funding in the future.  NextEra Energy Resources' portion of Seabrook's, Duane Arnold's and Point Beach's restricted funds for the payment of future expenditures to decommission these plants is included in nuclear decommissioning reserve funds, which are included in special use funds on NextEra Energy's consolidated balance sheets.  Marketable securities held in the decommissioning funds are clas sified as available for sale and are carried at fair value.  Market adjustments result in a corresponding adjustment to other comprehensive income (OCI), except for unrealized losses associated with marketable securities considered to be other than temporary, including any credit losses, which are recognized as other than temporary impairment losses on securities held in nuclear decommissioning funds in NextEra Energy's consolidated statements of income.  Fund earnings are recognized in income and are reinvested in the funds either on a pretax or after-tax basis.  See Note 5.  The tax effects of amounts not yet recognized for tax purposes are included in accumulated deferred income taxes.

Major Maintenance Costs - FPL uses the accrue-in-advance method for recognizing costs associated with planned major nuclear maintenance, in accordance with regulatory treatment, and records the related accrual as a regulatory liability.  FPL expenses costs associated with planned fossil maintenance as incurred.  FPL's estimated nuclear maintenance costs for each nuclear unit's next planned outage are accrued over the period from the end of the last outage to the end of the next planned outage.  Any difference between the estimated and actual costs is included in O&M expenses when known.  The accrued liability for nuclear maintenance costs at December 31, 2010 and 2009 totaled approximately $58 million and $47 million, respectively , and is included in regulatory liabilities - other.  For the years ended December 31, 2010, 2009 and 2008, FPL recognized approximately $100 million, $84 million and $75 million, respectively, in nuclear maintenance costs which are included in O&M expenses in NextEra Energy's and FPL's consolidated statements of income.

NextEra Energy Resources uses the deferral method to account for certain planned major maintenance costs.  NextEra Energy Resources' major maintenance costs for its nuclear generating units and combustion turbines are capitalized and amortized on a unit of production method over the period from the end of the last outage to the beginning of the next planned outage.  NextEra Energy Resources' capitalized major maintenance costs, net of accumulated amortization, totaled approximately $95 million and $106 million at December 31, 2010 and 2009, respectively, and are included in other assets.  For the years ended December 31, 2010, 2009 and 2008, NextEra Energy Resources recognized approximately $88 million, $73 million and $57 million in major maintenance costs which are included in O&M expenses in NextEra Energy's consolidated statements of income.

Cash Equivalents - Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less.

Restricted Cash - At December 31, 2010 and 2009, NextEra Energy had approximately $111 million ($39 million for FPL) and $134 million ($33 million for FPL), respectively, of restricted cash included in other current assets on NextEra Energy's and FPL's consolidated balance sheets, which is restricted primarily for margin cash collateral and debt service payments.  Where offsetting positions exist, restricted cash related to margin cash collateral is netted against derivative instruments.  See Note 3.

Allowance for Doubtful Accounts - FPL maintains an accumulated provision for uncollectible customer accounts receivable that is estimated using a percentage, derived from historical revenue and write-off trends, of the previous five months of revenue.  Additional amounts are included in the provision to address specific items that are not considered in the calculation described above.  NextEra Energy Resources regularly reviews collectibility of its receivables and establishes a provision for losses estimated as a percentage of accounts receivable based on the historical bad debt write-off trends for its retail electricity provider operations and, when necessary, using the specific identification method for all other receivables.

Inventory - FPL values materials, supplies and fossil fuel inventory using a weighted-average cost method.  NextEra Energy Resources' materials, supplies and fossil fuel inventories are carried at the lower of weighted-average cost or market, unless evidence indicates that the weighted-average cost (even if in excess of market) will be recovered with a normal profit upon sale in the ordinary course of business.

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Energy Trading - NextEra Energy provides full energy and capacity requirements services primarily to distribution utilities, which include load-following services and various ancillary services, in certain markets and engages in power and gas marketing and trading activities to optimize the value of electricity and fuel contracts and generating facilities, as well as to take advantage of expected favorable commodity price movements.  Trading contracts that meet the definition of a derivative are accounted for at fair value and realized gains and losses from all trading contracts, including those where physical delivery is required, are recorded net for all periods presented.  See Note 3.

Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve - In connection with the 2007 storm-recovery bond financing (see Note 9 - FPL), the net proceeds to FPL from the sale of the storm-recovery property were used primarily to reimburse FPL for its estimated net of tax deficiency in its storm and property insurance reserve (storm reserve) and provide for a storm and property insurance reserve fund (storm fund).  Upon the issuance of the storm-recovery bonds, the storm reserve deficiency was reclassified to securitized storm-recovery costs and is recorded as a regulatory asset on NextEra Energy's and FPL's consolidated balance sheets.  As storm-recovery charges are billed to customers, the securitized storm-recovery costs are amortized, the amount of w hich is included in depreciation and amortization on NextEra Energy's and FPL's consolidated statements of income.  Marketable securities held in the storm fund are classified as available for sale and are carried at fair value with market adjustments, including any other than temporary impairment losses, resulting in a corresponding adjustment to the storm reserve.  Fund earnings, net of taxes, are reinvested in the fund.  The tax effects of amounts not yet recognized for tax purposes are included in accumulated deferred income taxes.  The storm fund is included in special use funds on NextEra Energy's and FPL's consolidated balance sheets and was approximately $125 million and $123 million at December 31, 2010 and 2009, respectively.  See Note 5.

The storm reserve that was reestablished in an FPSC financing order related to the issuance of the storm-recovery bonds is not reflected in NextEra Energy's and FPL's consolidated balance sheets as of December 31, 2010 or 2009 because the associated regulatory asset does not meet the specific recognition criteria under regulatory accounting guidance.  As a result, the storm reserve will be recognized as a regulatory liability as the storm-recovery charges are billed to customers and charged to depreciation and amortization on NextEra Energy's and FPL's consolidated statements of income.  Although NextEra Energy's and FPL's consolidated balance sheets as of December 31, 2010 reflect a storm reserve of approximately $43 million (included in regulatory liabilities - other on NextEra Energy's and FPL's consol idated balance sheets), FPL had the capacity to absorb up to approximately $205 million in future prudently incurred storm restoration costs without seeking recovery through a rate adjustment from the FPSC or filing a petition with the FPSC.

Impairment of Long-Lived Assets - NextEra Energy evaluates on an ongoing basis the recoverability of its assets for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable.  An impairment loss is required to be recognized if the carrying value of the asset exceeds the undiscounted future net cash flows associated with that asset.  The impairment loss to be recognized is the amount by which the carrying value of the long-lived asset exceeds the asset's fair value.  In most instances, the fair value is determined by discounting estimated future cash flows using an appropriate interest rate.

Goodwill and Other Intangible Assets - NextEra Energy's goodwill and other intangible assets are as follows:

	Weighted Average Useful Lives	December 31,
	(Years)	2010		2009
		(millions)
Goodwill:
Merchant reporting unit		$	72	$	72
Wind reporting unit			45		41
Total goodwill		$	117	$	113
Other intangible assets:
Purchase power agreements	19	$	87	$	87
Customer lists	7		34		28
Other, primarily land and transmission rights, permits and licenses	27		249		216
Total			370		331
Less accumulated amortization			93		78
Total other intangible assets - net		$	277	$	253

NextEra Energy Resources has recorded goodwill related to various acquisitions which were accounted for using the purchase method of accounting.  NextEra Energy Resources' other intangible assets are amortized, primarily on a straight-line basis, over their estimated useful lives.  For the years ended December 31, 2010, 2009 and 2008, amortization expense was approximately $18 million, $14 million and $13 million, respectively, and is expected to be approximately $14 million, $13 million, $10 million, $8 million and $6 million for 2011, 2012, 2013, 2014 and 2015, respectively.

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NextEra Energy Resources' goodwill and other intangible assets are included in other assets on NextEra Energy's consolidated balance sheets.  Goodwill is assessed for impairment at least annually by applying a fair value-based test.  Other intangible assets are periodically reviewed when impairment indicators are present to assess recoverability from future operations using undiscounted future cash flows.

Pension and Other Postretirement Plans - NextEra Energy allocates net periodic pension benefit income to its subsidiaries based on the pensionable earnings of the subsidiaries' employees; net periodic supplemental executive retirement plan (SERP) benefit costs to its subsidiaries based upon actuarial calculations by participant; and postretirement health care and life insurance benefits (other benefits) net periodic benefit costs to its subsidiaries based upon the number of eligible employees at each subsidiary.

NextEra Energy's regulatory assets and liabilities were established in association with the implementation of accounting guidance in a prior year which requires recognition of the funded status of benefit plans in the balance sheet, with changes in the funded status recognized in comprehensive income within shareholders' equity in the year in which the changes occur.  Since NextEra Energy is the plan sponsor, and its subsidiaries do not have separate rights to the plan assets or direct obligations to their employees, the results of implementing the accounting guidance were reflected at NextEra Energy and not allocated to the subsidiaries.  The portion of previously unrecognized actuarial gains and losses, prior service costs or credits and transition obligations that were estimated to be allocable to FPL as net per iodic benefit (income) cost in future periods and that otherwise would have been recorded in accumulated other comprehensive income (AOCI) were classified as regulatory assets and liabilities at NextEra Energy in accordance with regulatory treatment.

Stock-Based Compensation - NextEra Energy accounts for stock-based payment transactions based on grant-date fair value.  Compensation costs for awards with graded vesting are recognized on a straight-line basis over the requisite service period for the entire award.  See Note 11 - Stock-Based Compensation.

Retirement of Long-Term Debt - Gains and losses that result from differences in FPL's reacquisition cost and the book value of long-term debt which is retired are deferred as a regulatory asset or liability and amortized to interest expense ratably over the remaining life of the original issue, which is consistent with its treatment in the ratemaking process.  Capital Holdings recognizes such differences as other income (deductions) at the time of retirement.

Income Taxes - Deferred income taxes are provided on all significant temporary differences between the financial statement and tax bases of assets and liabilities.  In connection with the tax sharing agreement between NextEra Energy and its subsidiaries, the income tax provision at each subsidiary reflects the use of the "separate return method," except that tax benefits that could not be used on a separate return basis, but are used on the consolidated tax return, are recorded by the subsidiary that generated the tax benefits.  Any remaining consolidated income tax benefits or expenses are recorded at the corporate level.  Included in other regulatory assets on NextEra Energy's and FPL's consolidated balance sheets is the revenue equivalent of the difference in accumulated deferred income taxes computed under accounting rules, as compared to regulatory accounting rules.  This amount totaled $151 million and $137 million at December 31, 2010 and 2009, respectively, and is being amortized in accordance with the regulatory treatment over the estimated lives of the assets or liabilities for which the deferred tax amount was initially recognized.  Investment tax credits (ITCs) for FPL are deferred and amortized to income over the approximate lives of the related property in accordance with the regulatory treatment.  At December 31, 2010 and 2009, deferred ITCs were approximately $7 million and $8 million, respectively, and are included in other regulatory liabilities on NextEra Energy's and FPL's consolidated balance sheets.  NextEra Energy Resources recognizes ITCs as a reduction to income tax expense when the related energy property is placed into service.  Production tax credits (PTCs) are reco gnized as wind energy is generated and sold based on a per kwh rate prescribed in applicable federal and state statutes and are recorded as a reduction of current income taxes payable, unless limited by tax law in which instance they are recorded as deferred tax assets.  NextEra Energy and FPL record a deferred income tax benefit created by the convertible ITCs on the difference between the financial statement and tax bases of renewable property.  For NextEra Energy Resources, this deferred income tax benefit is recorded in income tax expense in the year that the renewable property is placed in service.  For FPL, this deferred income tax benefit is offset by a regulatory liability, which is amortized as a reduction of depreciation expense over the approximate lives of the related renewable property in accordance with the regulatory treatment.  At December 31, 2010 and 2009, the net deferred income tax benefits associated with the convertible ITCs were approximatel y $58 million and $14 million, respectively, and are included in other regulatory assets and regulatory liabilities on NextEra Energy's and FPL's consolidated balance sheets.  A valuation allowance is recorded to reduce the carrying amounts of deferred tax assets when it is more likely than not that such assets will not be realized.  All tax positions taken by NextEra Energy in its income tax returns that are recognized in the financial statements must satisfy a more-likely-than-not threshold.  See Note 6.

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Sale of Differential Membership Interests - Certain indirect wholly-owned subsidiaries of NextEra Energy Resources sold their Class B membership interest in entities that have ownership interests in wind facilities to third-party investors.  Information related to these sales is as follows:

Date	Proceeds			Generating Capacity	Wind Facilities
	(millions)			(mw)
December 2007		$705		598	Logan Wind, Mower County Wind, Oliver County Wind I and II, and Peetz Table Wind
April 2010		$190		170	Ashtabula Wind II and Wilton Wind II
September 2010		$75	(a)	309	Crystal Lake I, Langdon Wind and Langdon Wind II

¾¾¾¾¾¾¾¾¾¾

(a)   NextEra Energy will receive future capital contributions from the third-party investor on a semi-annual basis through December 31, 2018 based on the amount of PTCs generated by the facilities.  At December 31, 2010, the future capital contributions are expected to total approximately $207 million based on projected wind generation.

In exchange for the cash received, the holders of the Class B membership interests will receive a portion of the economic attributes of the facilities, including tax attributes, for a variable period.  Recognition of the proceeds from the sale of the differential membership interests was deferred and is recorded in deferral related to differential membership interests on NextEra Energy's consolidated balance sheets.  The deferred amount is being recognized as an adjustment to taxes other than income taxes and other in NextEra Energy's consolidated statements of income as the Class B members receive their portion of the economic attributes.  NextEra Energy continues to operate and manage the wind facilities, and consolidates the entities that own the wind facilities.

Guarantees - NextEra Energy's and FPL's payment guarantees and related contracts provided to unconsolidated entities entered into after December 31, 2002, for which it or a subsidiary is the guarantor, are recorded at fair value.  See Note 14 - Commitments.

Variable Interest Entities (VIEs) - Effective January 1, 2010, NextEra Energy and FPL adopted new accounting guidance which modified the consolidation model in previous guidance and expanded the disclosures related to VIEs.  An entity is considered to be a VIE when its total equity investment at risk is not sufficient to permit the entity to finance its activities without additional subordinated financial support, or its equity investors, as a group, lack the characteristics of having a controlling financial interest.  A reporting company is required to consolidate a VIE as its primary beneficiary when it has both the power to direct the activities of the VIE that most significantly impact the VIE's economic performance, and the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE.  Upon adoption of this new accounting guidance, neither NextEra Energy nor FPL was required to consolidate any additional VIEs or deconsolidate any VIEs.  NextEra Energy and FPL evaluate whether an entity is a VIE whenever reconsideration events as defined by the accounting guidance occur.  See Note 9.

2.  Employee Retirement Benefits

Employee Benefit Plans and Other Postretirement Plan - NextEra Energy sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NextEra Energy and its subsidiaries.  NextEra Energy also has a SERP, which includes a non-qualified supplemental defined benefit pension component that provides benefits to a select group of management and highly compensated employees.  The impact of this SERP component is included within pension benefits in the following tables, and was not material to NextEra Energy's financial statements for the years ended December 31, 2010, 2009 and 2008.  In addition to pension benefits, NextEra Energy sponsors a contributory postretirement plan for other benefits for retirees of NextEr a Energy and its subsidiaries meeting certain eligibility requirements.

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Plan Assets, Benefit Obligations and Funded Status - The changes in assets and benefit obligations of the plans and the plans' funded status are as follows:

	Pension Benefits						Other Benefits
	2010			2009			2010			2009
	(millions)
Change in plan assets:
Fair value of plan assets at January 1	$	3,028		$	2,503		$	32		$	29
Actual return on plan assets		380			656			2			5
Employer contributions(a)		3			-			28			29
Transfers(b)		(29	)		(29	)		-			-
Participant contributions		-			-			9			7
Benefit payments(a)		(149	)		(102	)		(39	)		(38	)
Fair value of plan assets at December 31	$	3,233		$	3,028		$	32		$	32
Change in benefit obligation:
Obligation at January 1	$	1,866		$	1,604		$	430		$	367
Service cost		59			51			6			5
Interest cost		102			109			23			24
Participant contributions		-			-			9			7
Plan amendments(c)		1			3			-			(1	)
Special termination benefits(d)		13			-			-			-
Actuarial losses (gains) - net		102			201			(12	)		66
Benefit payments		(149	)		(102	)		(39	)		(38	)
Obligation at December 31(e)	$	1,994		$	1,866		$	417		$	430
Funded status:
Prepaid (accrued) benefit cost at NextEra Energy at December 31	$	1,239		$	1,162		$	(385	)	$	(398	)
Prepaid (accrued) benefit cost at FPL at December 31	$	1,027		$	1,009		$	(279	)	$	(282	)

¾¾¾¾¾¾¾¾¾¾

(a)	Employer contributions and benefit payments include only those amounts contributed directly to, or paid directly from, plan assets.  FPL's portion of contributions related to SERP benefits was $1 million for 2010.  FPL's portion of contributions related to other benefits was $26 million and $27 million for 2010 and 2009, respectively.
(b)	Represents amounts that were transferred from the qualified pension plan as reimbursement for eligible retiree medical expenses paid by NextEra Energy pursuant to the provisions of the Internal Revenue Code (IRC).
(c)	Primarily relates to union negotiated credits, IRC transfers and various SERP and other benefits amendments.
(d)	Reflects an enhanced early retirement program offered during 2010.
(e)	NextEra Energy's accumulated benefit obligation, which includes no assumption about future salary levels, for its pension plans at December 31, 2010 and 2009 was $1,935 million and $1,804 million, respectively.

NextEra Energy's and FPL's prepaid (accrued) benefit cost shown above are included in the consolidated balance sheets as follows:

	NextEra Energy													FPL
	Pension Benefits						Other Benefits							Pension Benefits							Other Benefits
	2010			2009			2010			2009				2010				2009			2010			2009
										(millions)
Prepaid benefit costs	$	1,259		$	1,184		$	-			$	-			$	1,035		$	1,017		$	-		$	-
Accrued benefit cost included in other current liabilities		(3	)		(2	)		(27	)			(29	)			(2	)		(2	)		(23	)		(24	)
Accrued benefit cost included in other liabilities		(17	)		(20	)		(358	)			(369	)			(6	)		(6	)		(256	)		(258	)
Prepaid (accrued) benefit cost at December 31	$	1,239		$	1,162		$	(385	)		$	(398	)		$	1,027		$	1,009		$	(279	)	$	(282	)

NextEra Energy's unrecognized amounts included in accumulated other comprehensive income (loss) yet to be recognized as components of prepaid (accrued) benefit cost are as follows:

	Pension Benefits						Other Benefits
	2010			2009			2010			2009
				(millions)
Components of AOCI:
Unrecognized prior service benefit (cost) (net of $2 and $2 tax benefit, respectively)	$	(4	)	$	(3	)	$	-		$	-
Unrecognized transition obligation (net of $1 and $1 tax benefit, respectively)		-			-			(1	)		(1	)
Unrecognized gain (loss) (net of $5 tax expense, $4 tax expense, $5 tax benefit and $6 tax benefit, respectively)		8			7			(4	)		(6	)
Total	$	4	(a)	$	4		$	(5	)(b)	$	(7	)

¾¾¾¾¾¾¾¾¾¾

(a)	Approximately $1 million of prior service benefits is expected to be reclassified into earnings within the next 12 months.
(b)	Approximately $1 million of transition obligations is expected to be reclassified into earnings within the next 12 months.

77

NextEra Energy's unrecognized amounts included in regulatory assets (liabilities) yet to be recognized as components of net prepaid (accrued) benefit cost are as follows:

	Regulatory Assets (Liabilities) (Pension)						Regulatory Assets (SERP and Other)
	2010			2009			2010			2009
	(millions)
Unrecognized prior service cost	$	13		$	10		$	1		$	2
Unrecognized transition obligation		-			-			4			7
Unrecognized (gain) loss		(64	)		(28	)		37			45
Total	$	(51	)(a)	$	(18	)	$	42	(b)	$	54

¾¾¾¾¾¾¾¾¾¾

(a)	Approximately $1 million of prior service benefits will be reclassified into earnings within the next 12 months.
(b)	Approximately $2 million of transition obligations will be reclassified into earnings within the next 12 months.

The following table provides the weighted-average assumptions used to determine benefit obligations for the plans.  These rates are used in determining net periodic benefit cost in the following year.

	Pension Benefits		Other Benefits
	2010	2009	2010	2009
Discount rate	5.00%	5.50%	5.25%	5.50%
Salary increase	4.00%	4.00%	4.00%	4.00%

The projected 2011 trend assumption used to measure the expected cost of health care benefits covered by the plans for those under age 65 is 7.60% for medical and 8.20% for prescription drug benefits and for those age 65 and over is 7.25% for medical and 7.75% for prescription drug benefits.  These rates are assumed to decrease over the next 8 years for medical benefits and 10 years for prescription drug benefits to the ultimate trend rate of 5.50% and remain at that level thereafter.  The ultimate trend rate is assumed to be reached in 2018 for medical benefits and 2020 for prescription drug benefits.  Assumed health care cost trend rates have an effect on the amounts reported for postretirement plans providing health care benefits.  An increase or decrease of one percentage point in assumed he alth care cost trend rates would have a corresponding effect on the other benefits accumulated obligation of approximately $3 million at December 31, 2010.

NextEra Energy's investment policy for the pension plan recognizes the benefit of protecting the plan's funded status, thereby avoiding the necessity of future employer contributions.  Its broad objectives are to achieve a high rate of total return with a prudent level of risk taking while maintaining sufficient liquidity and diversification to avoid large losses and preserve capital over the long term.

NextEra Energy's pension plan fund has a strategic asset allocation that targets a mix of 45% equity investments, 45% fixed income investments and 10% convertible bonds.  The fund's investment strategy emphasizes traditional investments, broadly diversified across the global equity and fixed income markets, using a combination of different investment styles and vehicles.  The pension fund's equity investments include direct equity holdings and assets classified as equity commingled vehicles.  Similarly, its fixed income investments include direct debt security holdings and assets classified as debt security commingled vehicles.  These equity and debt security commingled vehicles include common and collective trusts, pooled separate accounts, registered investment companies or other forms of pool ed investment arrangements.

With regard to its other benefits plan, NextEra Energy's policy is to fund claims as incurred during the year through NextEra Energy contributions, participant contributions and plan assets.  The other benefits plan's assets are invested with a focus on assuring the availability of funds to pay benefits while maintaining sufficient diversification to avoid large losses and preserve capital.  The other benefits plan's fund has a strategic asset allocation that targets a mix of 60% equity investments and 40% fixed income investments.  The fund's investment strategy emphasizes traditional investments, diversified across the global equity and fixed income markets.  The fund's equity investments are comprised of assets classified as equity commingled vehicles.  Similarly, its fixed income i nvestments are comprised of assets classified as debt security commingled vehicles.  These equity and debt commingled vehicles include common and collective trusts, pooled separate accounts, registered investment companies or other forms of pooled investment arrangements.

78

The fair value measurements of NextEra Energy's pension plan assets by fair value hierarchy level are as follows:

	December 31, 2010(a)
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Total
	(millions)
Equity	$	800	(b)	$	6		$	-	$	806
Equity commingled vehicles		-			669	(c)		11		680
U.S. Government and municipal bonds		60			35			-		95
Corporate debt securities(d)		-			335			-		335
Mortgage-backed securities		-			263			-		263
Debt security commingled vehicles(e)		-			744			-		744
Convertible bonds		-			310			-		310
Total	$	860		$	2,362		$	11	$	3,233

¾¾¾¾¾¾¾¾¾¾¾¾

(a)	See Note 4 for discussion of NextEra Energy's fair value measurement techniques.
(b)	Includes foreign investments of $293 million.
(c)	Includes foreign investments of $219 million.
(d)	Includes foreign investments of $47 million.
(e)	Includes foreign investments of $56 million and $206 million of short-term commingled vehicles.

	December 31, 2009(a)
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(millions)
Equity	$	424	$	-	$	-	$	424
Equity commingled vehicles(b)		-		941		-		941
U.S. Government and municipal bonds		77		30		-		107
Corporate debt securities(c)		-		399		-		399
Mortgage-backed securities		-		361		-		361
Debt security commingled vehicles(d)		-		503		-		503
Convertible bonds		-		293		-		293
Total	$	501	$	2,527	$	-	$	3,028

¾¾¾¾¾¾¾¾¾¾¾¾

(a)	See Note 4 for discussion of NextEra Energy's fair value measurement techniques.
(b)	Includes foreign investments of $499 million.
(c)	Includes foreign investments of $45 million.
(d)	Includes foreign investments of $56 million and $53 million of short-term commingled vehicles.

The fair value measurements, all of which were Level 2, of NextEra Energy's other benefits plan assets at December 31, 2010 and 2009 were approximately $20 million and $19 million of equity commingled vehicles (of which $5 million and $4 million were foreign investments) and $12 million and $13 million of debt security commingled vehicles, respectively.

Expected Cash Flows - NextEra Energy anticipates paying approximately $28 million for eligible retiree medical expenses on behalf of the other benefits plan during 2011 with substantially all amounts being reimbursed through a transfer of assets from the qualified pension plan.

79

The following table provides information about benefit payments expected to be paid by the plans, net of government drug subsidy, for each of the following calendar years:

	Pension Benefits		Other Benefits
	(millions)
2011	$	173	$	34
2012	$	167	$	35
2013	$	169	$	34
2014	$	163	$	32
2015	$	159	$	32
2016 - 2020	$	814	$	153

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

	Pension Benefits									Other Benefits
	2010			2009			2008			2010			2009			2008
							(millions)
Service cost	$	59		$	51		$	54		$	6		$	5		$	5
Interest cost		102			109			102			23			24			25
Expected return on plan assets		(241	)		(239	)		(240	)		(2	)		(3	)		(3	)
Amortization of transition obligation		-			-			-			3			4			4
Amortization of prior service benefit		(3	)		(3	)		(4	)		-			-			-
Amortization of gains		1			(23	)		(29	)		-			-			-
SERP settlements		1			-			-			-			-			-
Special termination benefits		13			-			-			-			-			-
Net periodic benefit (income) cost at NextEra Energy	$	(68	)	$	(105	)	$	(117	)	$	30		$	30		$	31
Net periodic benefit (income) cost at FPL	$	(42	)	$	(73	)	$	(84	)	$	23		$	23		$	24

Other Comprehensive Income - The components of net periodic benefit income (cost) recognized in OCI for the plans are as follows:

	Pension Benefits						Other Benefits
	2010			2009			2010		2009
				(millions)
Prior service cost	$	-		$	(1	)	$	-	$	-
Net gains (losses) (net of none, $24 tax expense, $1 tax expense and $7 tax benefit, respectively)		1			38			2		(10	)
Transition obligation		-			-			-		(1	)
Amortization of prior service benefit		(1	)		(1	)		-		-
Amortization of net gains (net of $3 tax benefit)		-			(4	)		-		-
Amortization of transition obligation		-			-			-		1
Total	$	-		$	32		$	2	$	(10	)

Regulatory Assets (Liabilities) - The components of net periodic benefit (income) cost recognized during the year in regulatory assets (liabilities) for the plans are as follows:

	Regulatory Assets (Liabilities) (Pension)						Regulatory Assets (SERP and Other)
	2010			2009			2010			2009
	(millions)
Prior service cost	$	1		$	2		$	-		$	-
Unrecognized (gains) losses		(35	)		(159	)		(9	)		51
Transition obligation		-			-			-			(2	)
Amortization of prior service benefit		2			3			-			-
Amortization of gains		-			16			-			-
Amortization of transition obligation		-			-			(2	)		(3	)
Total	$	(32	)	$	(138	)	$	(11	)	$	46

80

The weighted-average assumptions used to determine net periodic benefit (income) cost for the plans are as follows:

	Pension Benefits			Other Benefits
	2010	2009	2008	2010	2009	2008
Discount rate	5.50%	6.90%	6.25%	5.50%	6.90%	6.35%
Salary increase	4.00%	4.00%	4.00%	4.00%	4.00%	4.00%
Expected long-term rate of return(a)	7.75%	7.75%	7.75%	8.00%	8.00%	8.00%

¾¾¾¾¾¾¾¾¾¾

(a)   In developing the expected long-term rate of return on assets assumption for its plans, NextEra Energy evaluated input from its actuaries as well as information available in the marketplace.  NextEra Energy considered the 10-year and 20-year historical median returns for a portfolio with an equity/bond asset mix similar to its funds.  NextEra Energy also considered its funds' historical compounded returns.  No specific adjustments were made to reflect expectations of future returns.

Assumed health care cost trend rates have an effect on the amounts reported for postretirement plans providing health care benefits.  An increase or decrease of one percentage point in assumed health care cost trend rates would have a corresponding effect on the total service and interest cost recognized at December 31, 2010 by less than $1 million.

Employee Contribution Plans - NextEra Energy offers employee retirement savings plans which allow eligible participants to contribute a percentage of qualified compensation through payroll deductions.  NextEra Energy makes matching contributions to participants' accounts.  Defined contribution expense pursuant to these plans was approximately $34 million, $38 million and $37 million for NextEra Energy ($26 million, $28 million and $28 million for FPL) for the years ended December 31, 2010, 2009 and 2008, respectively.  See Note 11 - Employee Stock Ownership Plan.

3.  Derivative Instruments

NextEra Energy 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, and to optimize the value of NextEra Energy Resources' power generation assets.

With respect to commodities related to NextEra Energy's competitive energy business, NextEra Energy Resources employs rigorous risk management procedures in order to optimize the value of its power generation assets, provide full energy and capacity requirements services primarily to distribution utilities, and engage in power and gas marketing and trading activities to take advantage of expected future favorable price movements and changes in the expected volatility of prices in the energy markets.  These risk management activities involve the use of derivative instruments executed within prescribed limits to manage the risk associated with fluctuating commodity prices.  Transactions in derivative instruments are executed on recognized exchanges or via the over-the-counter markets, depending on the most favorable credit terms and market execution factors.  For NextEra Energy Resources' 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 the expected energy output of these assets for the portion of the output that is not covered by long-term power purchase agreements (PPA).  These hedges protect NextEra Energy Resources against adverse changes in the wholesale forward commodity markets associated with its generation assets.  With regard to full energy and capacity requirements services, NextEra Energy Resources 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 ener gy markets.  Additionally, NextEra Energy Resources takes positions in the energy markets based on differences between actual forward market levels and management's view of fundamental market conditions.  NextEra Energy Resources 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 NextEra Energy's and FPL's consolidated balance sheets as either an asset or liability measured at fair value.  At FPL, substantially all changes in the derivatives' fair value are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the fuel and purchased power cost recovery clause (fuel clause) or the capacity clause.  For NextEra Energy's non-rate regulated operations, predominantly NextEra Energy Resources, 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 ba sis 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 NextEra Energy's consolidated statements of income.  Settlement gains and losses are included within the line items in the consolidated statements of income to which they relate.  Settlements related to derivative instruments are primarily recognized in net cash provided by operating activities in NextEra Energy's and FPL's consolidated statements of cash flows.

81

While most of NextEra Energy Resources' derivatives are entered into for the purpose of managing commodity price risk, and to reduce the impact of volatility in interest rates stemming from changes in variable interest rates on outstanding debt, 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 commodity price risk, physical delivery for forecasted commodity transactions must be probable.  NextEra Energy 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 deeme d 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 consolidated statements of income.  Generally, NextEra Energy assesses a hedging instrument's effectiveness by using regression analysis for commodity contracts, and 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 for interest rate swaps and foreign currency derivative instruments.  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 OCI and is reclassified into earnings in the period(s) during which the transaction being hedged affects earnings.  See Note 7.  The ine ffective portion of net unrealized gains (losses) on these hedges is reported in earnings in the current period.

In January 2010, NextEra Energy discontinued hedge accounting for its cash flow hedges related to commodity derivative instruments.  NextEra Energy continues to apply hedge accounting to certain interest rate and foreign currency hedges.  At December 31, 2010, NextEra Energy's AOCI included amounts related to the discontinued commodity cash flow hedges which have expiration dates through December 2012.  Additionally, at December 31, 2010, NextEra Energy had interest rate cash flow hedges with expiration dates through September 2028 and foreign currency cash flow hedges with expiration dates through September 2030.

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

	NextEra Energy						FPL
	December 31,						December 31,
	2010			2009			2010			2009
	(millions)
Current derivative assets(a)	$	506		$	357		$	8	(b)	$	10	(b)
Noncurrent other assets(c)		589			329			1			4
Current derivative liabilities(d)		(536	)		(221	)		(245	)		(77	)
Noncurrent derivative liabilities(e)		(243	)		(170	)		-			(1	)(f)
Total mark-to-market derivative instrument assets (liabilities)	$	316		$	295		$	(236	)	$	(64	)

¾¾¾¾¾¾¾¾¾¾

(a)	At December 31, 2010 and 2009, NextEra Energy's balances reflect the netting of approximately $23 million and $4 million (none at FPL), respectively, in margin cash collateral received from counterparties.
(b)	Included in current other assets on FPL's consolidated balance sheets.
(c)	At December 31, 2010 and 2009, NextEra Energy's balances reflect the netting of approximately $43 million and $1 million (none at FPL), respectively, in margin cash collateral received from counterparties.
(d)	At December 31, 2010 and 2009, NextEra Energy's balances reflect the netting of approximately $23 million and $75 million (none at FPL), respectively, in margin cash collateral provided to counterparties.
(e)	At December 31, 2010, NextEra Energy's balance reflects the netting of approximately $72 million (none at FPL) in margin cash collateral provided to counterparties.
(f)	Included in noncurrent other liabilities on FPL's consolidated balance sheets.

At December 31, 2010 and 2009, NextEra Energy had approximately $7 million and $18 million (none at FPL), respectively, in margin cash collateral received from counterparties that was not offset against derivative assets.  These amounts are included in other current liabilities in the consolidated balance sheets.  Additionally, at December 31, 2010 and 2009, NextEra Energy had approximately $58 million and $95 million (none at FPL), respectively, in margin cash collateral provided to counterparties that was not offset against derivative liabilities.  These amounts are included in other current assets in the consolidated balance sheets.

As discussed above, NextEra Energy 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 NextEra Energy's and FPL's net derivative positions at December 31, 2010 and 2009, 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.

82

The fair values of NextEra Energy's derivatives 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.

	December 31, 2010				December 31, 2009
	Derivative Assets		Derivative Liabilities		Derivative Assets		Derivative Liabilities
	(millions)
Commodity contracts:
Current derivative assets	$	-	$	-	$	54	$	1
Current derivative liabilities		-		-		45		4
Noncurrent other assets		-		-		44		2
Noncurrent derivative liabilities		-		-		8		13
Interest rate swaps:
Current derivative assets		16		-		-		-
Current derivative liabilities		-		64		-		51
Noncurrent other assets		91		-		61		-
Noncurrent derivative liabilities		-		59		-		27
Foreign currency swaps:
Current derivative assets		24		-		-		-
Current derivative liabilities		-		4		-		-
Noncurrent other assets		11		-		5		-
Total	$	142	$	127	$	217	$	98

Gains (losses) related to NextEra Energy's cash flow hedges are recorded on NextEra Energy's consolidated financial statements (none at FPL) as follows:

	Year Ended December 31, 2010												Year Ended December 31, 2009
	Commodity Contracts			Interest Rate Swaps			Foreign Currency Swaps			Total			Commodity Contracts			Interest Rate Swaps			Foreign Currency Swap			Total
	(millions)
Gains (losses) recognized in OCI	$	20		$	(52	)	$	24		$	(8	)	$	197		$	28		$	3		$	228
Gains (losses) reclassified from AOCI to net income	$	118	(a)	$	(65	)(b)	$	20	(c)	$	73		$	164	(a)	$	(39	)(b)	$	4	(e)	$	129
Gains (losses) recognized in income(d)	$	1	(a)	$	-		$	-		$	1		$	29	(a)	$	-		$	-		$	29

¾¾¾¾¾¾¾¾¾¾

(a)	Included in operating revenues.
(b)	Included in interest expense.
(c)	Loss of approximately $4 million is included in interest expense and the balance is included in other - net.
(d)	Represents the ineffective portion of the hedging instrument.
(e)	Loss of approximately $1 million is included in interest expense and the balance is included in other - net.

For the year ended December 31, 2010, NextEra Energy recorded a gain of approximately $11 million on three fair value hedges which is reflected in interest expense in the consolidated statements of income and resulted in a corresponding increase in the related debt.  For the year ended December 31, 2009, NextEra Energy recorded a loss of $6 million on a fair value hedge which is reflected in interest expense in the consolidated statements of income and resulted in a corresponding reduction of the related debt.

83

The fair values of NextEra Energy'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.

	December 31, 2010										December 31, 2009
	NextEra Energy				FPL						NextEra Energy				FPL
	Derivative Assets		Derivative Liabilities		Derivative Assets			Derivative Liabilities			Derivative Assets		Derivative Liabilities		Derivative Assets			Derivative Liabilities
	(millions)
Commodity contracts:
Current derivative assets	$	754	$	278	$	9	(a)	$	1	(a)	$	611	$	303	$	11	(a)	$	1	(a)
Current derivative liabilities		1,848		2,339		12			257			1,002		1,288		18			95
Noncurrent other assets		687		157		1			-			921		699		4			-
Noncurrent derivative liabilities		828		1,084		-			-			128		260		-			1	(b)
Foreign currency swap:
Current derivative assets		13		-		-			-			-		-		-			-
Noncurrent derivative liabilities		-		-		-			-			-		6		-			-
Total	$	4,130	$	3,858	$	22		$	258		$	2,662	$	2,556	$	33		$	97

¾¾¾¾¾¾¾¾¾¾

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

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

	Year Ended December 31,
	2010			2009
	(millions)
Commodity contracts:
Operating revenues	$	531	(a)	$	279	(a)
Fuel, purchased power and interchange		1			28
Foreign currency swap:
Other - net		18			(3	)
Total	$	550		$	304

¾¾¾¾¾¾¾¾¾¾

(a)   In addition, for the year ended December 31, 2010 and 2009, FPL recorded approximately $665 million and $688 million of losses, respectively, related to commodity contracts as regulatory assets on its consolidated balance sheets.

The following table represents net notional volumes associated with derivative instruments that are required to be reported at fair value in NextEra Energy's and FPL's consolidated financial statements.  The table includes significant volumes of transactions that have minimal exposure to commodity price changes because they are variably priced agreements.  The table does not present a complete picture of NextEra Energy's and FPL's overall net economic exposure because NextEra Energy and FPL do not use derivative instruments to hedge all of their commodity exposures.  At December 31, 2010, NextEra Energy and FPL had derivative commodity contracts for the following net notional volumes:

Commodity Type	NextEra Energy			FPL
	(millions)
Power	(62	)	mwh(a)	-
Natural gas	1,009		mmbtu(b)	794	mmbtu(b)

¾¾¾¾¾¾¾¾¾¾

(a)	Megawatt-hours
(b)	One million British thermal units

At December 31, 2010, NextEra Energy had 23 interest rate swaps with a notional amount totaling approximately $4.3 billion and three foreign currency swaps with a notional amount totaling approximately $408 million.

Certain of NextEra Energy'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 December 31, 2010, the aggregate fair value of NextEra Energy's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately $1.6 billion ($0.3 billion for FPL).

84

If the credit-risk-related contingent features underlying these agreements and other wholesale commodity contracts were triggered, NextEra Energy 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 Capital Holdings' and FPL's credit ratings were downgraded to BBB/Baa2 (a two level downgrade for FPL and a one level downgrade for Capital Holdings from the current lowest applicable rating), NextEra Energy would be required to post collateral such that the t otal posted collateral would be approximately $400 million ($100 million at FPL).If Capital Holdings' and FPL's credit ratings were downgraded to below investment grade, NextEra Energy would be required to post additional collateral such that the total posted collateral would be approximately $2.1 billion ($0.8 billion at FPL).  Some contracts at NextEra Energy, 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, NextEra Energy 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 December 31, 2010, NextEra Energy had posted approximately $115 million ($5 million 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 Capital Holdings have bank revolving line of 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 bank revolving line of 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, NextEra Energy and FPL are unable to determine an exact value for these items and they are not included in any of the quantitative disclosures above.

4.  Fair Value Measurements

NextEra Energy 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.  NextEra Energy'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 is also considered in the determination of fair value for all assets and liabilities measured at fair value, including the consideration of a credit valuation adjustment.

Cash Equivalents - Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less.  NextEra Energy 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 - NextEra Energy 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 - NextEra Energy and FPL measure the fair value of commodity contracts on a daily basis using prices observed on commodities exchanges and in the over-the-counter 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.

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.

85

NextEra Energy and FPL also enter into over-the-counter 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 exchange markets are deemed to be inactive or do not have a similar contract that trades on an exchange, 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 p oints.

NextEra Energy, through NextEra Energy Resources, 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 NextEra Energy have one or more significant inputs that are not observable, and are valued using industry-standard option models.

In all cases where NextEra Energy 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 includes, but is not limited to, assumptions about market liquidity, volatility and contract duration.

NextEra Energy 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.  NextEra Energy 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.  Non-performance risk is also considered in the determination of fair value for all derivative assets and liabilities, including the consideration of a credit valuation adjustment.

86

NextEra Energy's and FPL's financial assets and liabilities and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows:

	December 31, 2010
	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:
NextEra Energy - equity securities	$	-	$	122		$	-	$	-		$	122
FPL - equity securities	$	-	$	7		$	-	$	-		$	7
Special use funds:
NextEra Energy:
Equity securities	$	741	$	1,245	(b)	$	-	$	-		$	1,986
U.S. Government and municipal bonds	$	495	$	127		$	-	$	-		$	622
Corporate debt securities	$	-	$	486		$	-	$	-		$	486
Mortgage-backed securities	$	-	$	447		$	-	$	-		$	447
Other debt securities	$	-	$	108		$	-	$	-		$	108
FPL:
Equity securities	$	125	$	1,082	(b)	$	-	$	-		$	1,207
U.S. Government and municipal bonds	$	458	$	111		$	-	$	-		$	569
Corporate debt securities	$	-	$	334		$	-	$	-		$	334
Mortgage-backed securities	$	-	$	381		$	-	$	-		$	381
Other debt securities	$	-	$	41		$	-	$	-		$	41
Other investments:
NextEra Energy:
Equity securities	$	3	$	1		$	-	$	-		$	4
U.S. Government and municipal bonds	$	8	$	4		$	-	$	-		$	12
Corporate debt securities	$	-	$	32		$	-	$	-		$	32
Mortgage-backed securities	$	-	$	58		$	-	$	-		$	58
Other	$	5	$	10		$	-	$	-		$	15
Derivatives:
NextEra Energy:
Commodity contracts	$	1,755	$	1,538		$	824	$	(3,177	)	$	940	(c)
Interest rate swaps	$	-	$	107		$	-	$	-		$	107	(c)
Foreign currency swaps	$	-	$	48		$	-	$	-		$	48	(c)
FPL - commodity contracts	$	-	$	14		$	8	$	(13	)	$	9	(c)
Liabilities:
Derivatives:
NextEra Energy:
Commodity contracts	$	1,821	$	1,509		$	528	$	(3,206	)	$	652	(c)
Interest rate swaps	$	-	$	123		$	-	$	-		$	123	(c)
Foreign currency swaps	$	-	$	4		$	-	$	-		$	4	(c)
FPL - commodity contracts	$	-	$	257		$	1	$	(13	)	$	245	(c)

¾¾¾¾¾¾¾¾¾¾

(a)	Includes the effect of the contractual ability to settle contracts under master netting arrangements and margin cash collateral payments and receipts.
(b)	At NextEra Energy, approximately $1,084 million ($980 million at FPL) are invested in commingled funds whose underlying investments would be Level 1 if those investments were held directly by NextEra Energy or FPL.
(c)	See Note 3 for a reconciliation of net derivatives to NextEra Energy's and FPL's consolidated balance sheets.

87

	December 31, 2009
	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:
NextEra Energy - equity securities		$	-		$	79			$	-	$	-		$		79
FPL - equity securities		$	-		$	43			$	-	$	-		$		43
Special use funds:
NextEra Energy:
Equity securities		$	657		$	1,048	(b)		$	-	$	-		$		1,705
U.S. Government and municipal bonds		$	275		$	299			$	-	$	-		$		574
Corporate debt securities		$	-		$	452			$	-	$	-		$		452
Mortgage-backed securities		$	-		$	618			$	-	$	-		$		618
Other debt securities		$	-		$	41			$	-	$	-		$		41
FPL:
Equity securities		$	104		$	920	(b)		$	-	$	-		$		1,024
U.S. Government and municipal bonds		$	230		$	278			$	-	$	-		$		508
Corporate debt securities		$	-		$	346			$	-	$	-		$		346
Mortgage-backed securities		$	-		$	503			$	-	$	-		$		503
Other debt securities		$	-		$	27			$	-	$	-		$		27
Other investments:
NextEra Energy:
Equity securities		$	3		$	4			$	-	$	-		$		7
U.S. Government and municipal bonds		$	-		$	38			$	-	$	-		$		38
Corporate debt securities		$	-		$	35			$	-	$	-		$		35
Mortgage-backed securities		$	-		$	31			$	-	$	-		$		31
Other		$	4		$	-			$	-	$	-		$		4
Derivatives:
NextEra Energy		$	988		$	1,089			$	801	$	(2,192	)	$		686	(c)
FPL		$	-		$	20			$	13	$	(19	)	$		14	(c)
Liabilities:
Derivatives:
NextEra Energy		$	1,110		$	1,106			$	437	$	(2,262	)	$		391	(c)
FPL		$	-		$	95			$	2	$	(19	)	$		78	(c)

¾¾¾¾¾¾¾¾¾¾

(a)	Includes the effect of the contractual ability to settle contracts under master netting arrangements and margin cash collateral payments and receipts.
(b)	At NextEra Energy, approximately $918 million ($836 million at FPL) are invested in commingled funds whose underlying investments would be Level 1 if those investments were held directly by NextEra Energy or FPL.
(c)	See Note 3 for a reconciliation of net derivatives to NextEra Energy's and FPL's consolidated balance sheets.

88

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

	Year Ended December 31,
	2010						2009
	NextEra Energy			FPL			NextEra Energy			FPL
	(millions)
Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year	$	364		$	11		$	404		$	(1	)
Realized and unrealized gains (losses):
Included in earnings(a)		407			-			555			-
Included in regulatory assets and liabilities		1			1			7			7
Purchases, sales, settlements and net option premiums		(432	)		(5	)		(521	)		6
Net transfers in/out(b)		(44	)		-			(81	)		(1	)
Fair value of net derivatives based on significant unobservable inputs at December 31	$	296		$	7		$	364		$	11
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)	$	170		$	-		$	270		$	-

¾¾¾¾¾¾¾¾¾¾

(a)	For the year ended December 31, 2010 and 2009, $384 million and $555 million, respectively, of realized and unrealized gains are reflected in operating revenues in the consolidated statements of income.  For the year ended December 31, 2010, $23 million of realized and unrealized gains are reflected in fuel, purchased power and interchange in the consolidated statements of income.
(b)	For the year ended December 31, 2010, gross transfers of $2 million into Level 3 were a result of decreased observability of market data, and gross transfers of $46 million from Level 3 to Level 2 were a result of increased observability of market data.  NextEra Energy's and FPL's policy is to recognize all transfers at the beginning of the reporting period.
(c)	For the year ended December 31, 2010 and 2009, $153 million and $270 million, respectively, of unrealized gains are reflected in operating revenues in the consolidated statements of income.  For the year ended December 31, 2010, $17 million of unrealized gains are reflected in fuel, purchased power and interchange in the consolidated statements of income.

5.  Financial Instruments

NextEra Energy and FPL adopted new accounting and disclosure provisions related to other than temporary impairments and the fair value of financial instruments beginning April 1, 2009.  Under the new accounting provisions, an investment in a debt security is required to be assessed for an other than temporary impairment based on whether the entity has an intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized cost basis.  Additionally, if the entity does not expect to recover the amortized cost of a debt security, an impairment is recognized in earnings equal to the estimated credit loss.  For debt securities held as of April 1, 2009 for which an other than temporary impairment had been previously recognized but for which assessment unde r the new accounting provisions indicates the impairment is temporary, NextEra Energy recorded an adjustment to increase April 1, 2009 retained earnings by approximately $5 million with a corresponding reduction in AOCI.

The carrying amounts of cash equivalents, notes payable and commercial paper approximate their fair values.  At December 31, 2010 and 2009, other investments of NextEra Energy, not included in the table below, included financial instruments of approximately $97 million and $44 million, respectively, including $48 million and $5 million included in other current receivables on the consolidated balance sheets, which primarily consist of notes receivable that are carried at estimated fair value or cost, which approximates fair value.

89

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.

	December 31, 2010						December 31, 2009
	Carrying Amount			Estimated Fair Value			Carrying Amount			Estimated Fair Value
	(millions)
NextEra Energy:
Special use funds	$	3,742	(a)	$	3,742	(b)	$	3,390	(a)	$	3,390	(b)
Other investments:
Notes receivable	$	525		$	583	(c)	$	534		$	556	(c)
Debt securities	$	114	(d)	$	114	(b)	$	104	(d)	$	104	(b)
Equity securities	$	57		$	125	(e)	$	45		$	105	(e)
Long-term debt, including current maturities	$	19,929		$	20,756	(f)	$	16,869		$	17,256	(f)
Interest rate swaps - net unrealized losses	$	(16	)	$	(16	)(g)	$	(17	)	$	(17	)(g)
Foreign currency swaps - net unrealized gains (losses)	$	44		$	44	(g)	$	(1	)	$	(1	)(g)
FPL:
Special use funds	$	2,637	(a)	$	2,637	(b)	$	2,408	(a)	$	2,408	(b)
Long-term debt, including current maturities	$	6,727		$	7,236	(f)	$	5,836		$	6,055	(f)

¾¾¾¾¾¾¾¾¾¾

(a)	At December 31, 2010, includes $76 million of investments accounted for under the equity method and $17 million of loans not measured at fair value on a recurring basis ($94 million and $11 million, respectively, for FPL).  For the remaining balance, see Note 4 for classification by major security type.  The amortized cost of debt and equity securities is $1,616 million and $1,489 million, respectively, at December 31, 2010 and $1,638 million and $1,396 million, respectively, at December 31, 2009 ($1,281 million and $943 million, respectively, at December 31, 2010 and $1,344 million and $873 million, respectively, at December 31, 2009 for FPL).
(b)	Based on quoted market prices for these or similar issues.
(c)	Classified as held to maturity.  Based on market prices provided by external sources.  Notes receivable bear interest at variable rates based on an underlying index plus a margin and mature from 2014 to 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 December 31, 2010, neither NextEra Energy nor FPL had any material notes receivable reported in non-accrual status.
(d)	Classified as trading securities.
(e)	Modeled internally based on latest market data.
(f)	Provided by external sources based on market prices indicative of market conditions.
(g)	Modeled internally based on market values using discounted cash flow analysis and credit valuation adjustment.

Special Use Funds - The special use funds consist of FPL's storm fund assets of $125 million and NextEra Energy's and FPL's nuclear decommissioning fund assets of $3,617 million and $2,512 million, respectively, at December 31, 2010.  The majority of investments held in the special use funds consist of equity and debt securities which are classified as available for sale and are carried at estimated fair value (see Note 4).  For FPL's special use funds, consistent with regulatory treatment, market adjustments, including any other than temporary impairment losses, result in a corresponding adjustment to the related regulatory liability accounts.  For NextEra Energy's non-rate regulated operations, market adjustments result in a correspondin g adjustment to OCI, except for unrealized losses associated with marketable securities considered to be other than temporary, including any credit losses, which are recognized as other than temporary impairment losses on securities held in nuclear decommissioning funds in NextEra Energy's consolidated statements of income.  Debt securities included in the nuclear decommissioning funds have a weighted-average maturity at December 31, 2010 of approximately six years at both NextEra Energy and FPL.  FPL's storm fund primarily consists of debt securities with a weighted-average maturity at December 31, 2010 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 of available for sale securities are as follows:

	NextEra Energy									FPL
	Years Ended December 31,									Years Ended December 31,
	2010			2009			2008			2010			2009			2008
	(millions)
Realized gains		$	106		$	108		$	50		$	49		$	48		$	38
Realized losses		$	30		$	30		$	54		$	22		$	25		$	50
Proceeds from sale of securities		$	6,726		$	4,592		$	2,235		$	5,079		$	3,270		$	1,454

90

Unrealized losses on available for sale debt securities at December 31, 2010 and 2009 were not material to NextEra Energy or FPL.  The unrealized gains on available for sale securities are as follows:

	NextEra Energy					FPL
	December 31,					December 31,
	2010		2009			2010			2009
			(millions)
Equity securities	$	612		$	400		$	384	$	240
U.S. Government and municipal bonds	$	15		$	14		$	15	$	13
Corporate debt securities	$	23		$	21		$	19	$	16
Mortgage-backed securities	$	20		$	22		$	18	$	18
Other debt securities	$	2		$	1		$	1	$	1

Regulations issued by the FERC and the NRC provide general risk management guidelines to protect nuclear decommissioning funds and to allow such funds to earn a reasonable return.  The FERC regulations prohibit investments in any securities of NextEra Energy or its subsidiaries, affiliates or associates, excluding investments tied to market indices or mutual funds.  Similar restrictions applicable to the decommissioning funds for NextEra Energy Resources' nuclear plants are contained in the NRC operating licenses for those facilities or in NRC regulations applicable to NRC licensees not in cost-of-service environments.  With respect to the decommissioning fund for Seabrook, decommissioning fund contributions and withdrawals are also regulated by the NDFC pursuant to New Hampshire law.

The nuclear decommissioning reserve funds are managed by investment managers who must comply with the guidelines of NextEra Energy and FPL and 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 - NextEra Energy 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, Capital Holdings has entered into cross currency swaps, two to hedge against currency movements with respect to both interest and principal payments and another to hedge against currency and interest rate movements with respect to both interest and principal payments.  See Note 3.

6.  Income Taxes

The components of income taxes are as follows:

	NextEra Energy								FPL
	Years Ended December 31,								Years Ended December 31,
	2010		2009			2008			2010		2009		2008
	(millions)
Federal:
Current(a)	$	11	$	(18	)	$	(132	)	$	113	$	63	$	117
Deferred		434		290			542			385		342		259
Total federal		445		272			410			498		405		376
State:
Current(a)		11		77			29			49		57		34
Deferred		76		(22	)		11			33		11		33
Total state		87		55			40			82		68		67
Total income taxes	$	532	$	327		$	450		$	580	$	473	$	443

¾¾¾¾¾¾¾¾¾¾

(a)   Includes provision for unrecognized tax benefits.

91

A reconciliation between the effective income tax rates and the applicable statutory rates is as follows:

	NextEra Energy									FPL
	Years Ended December 31,									Years Ended December 31,
	2010			2009			2008			2010			2009			2008
Statutory federal income tax rate		35.0	%		35.0	%		35.0	%		35.0	%		35.0	%		35.0	%
Increases (reductions) resulting from:
State income taxes - net of federal income tax benefit		2.4			1.9			1.3			3.5			3.4			3.5
Allowance for other funds used during construction		(0.5	)		(1.0	)		(0.6	)		(0.8	)		(1.5	)		(1.1	)
Amortization of ITCs - FPL		(0.1	)		(0.4	)		(0.7	)		(0.2	)		(0.6	)		(1.2	)
PTCs and ITCs - NextEra Energy Resources		(12.2	)		(13.1	)		(12.7	)		-			-			-
Convertible ITCs - NextEra Energy Resources		(2.5	)		(4.3	)		-			-			-			-
Other - net		(0.7	)		(1.2	)		(0.7	)		0.5			-			(0.3	)
Effective income tax rate		21.4	%		16.9	%		21.6	%		38.0	%		36.3	%		35.9	%

The income tax effects of temporary differences giving rise to consolidated deferred income tax liabilities and assets are as follows:

	NextEra Energy						FPL
	December 31,						December 31,
	2010			2009			2010		2009
	(millions)
Deferred tax liabilities:
Property-related	$	7,795		$	6,968		$	4,532	$	4,202
Pension		485			457			399		392
Storm reserve deficiency		258			279			258		279
Nuclear decommissioning trusts		146			201			-		-
Net unrealized gains on derivatives		226			116			-		-
Deferred fuel costs		101			-			101		-
Other		638			371			187		157
Total deferred tax liabilities		9,649			8,392			5,477		5,030
Deferred tax assets and valuation allowance:
Decommissioning reserves		393			379			323		313
Postretirement benefits		175			183			130		133
Net operating loss carryforwards		663	(a)		270	(a)		-		-
Tax credit carryforwards		1,819	(b)		1,364	(b)		-		-
ARO and accrued asset removal costs		895			896			802		811
Other		790			683			309		249
Valuation allowance(c)		(246	)		(129	)		-		-
Net deferred tax assets		4,489			3,646			1,564		1,506
Net accumulated deferred income taxes	$	5,160		$	4,746		$	3,913	$	3,524

¾¾¾¾¾¾¾¾¾¾

(a)	Reflects $42 million and $(26) million, respectively, of tax carryforwards related to NextEra Energy's unrecognized tax benefits.
(b)	Amount is presented net of $52 million and $58 million, respectively, of tax carryforwards that are available to offset NextEra Energy's liability for unrecognized tax benefits.
(c)	Amount relates to deferred state tax credits and state operating loss carryforwards.

Deferred tax assets and liabilities are included in the consolidated balance sheets as follows:

	NextEra Energy							FPL
	December 31,							December 31,
	2010			2009				2010				2009
				(millions)
Other current assets	$	17			$	128			$	-		$	-
Other assets		106				-				-			-
Other current liabilities		(174	)			(14	)			(78	)		(15	)
Accumulated deferred income taxes		(5,109	)			(4,860	)			(3,835	)		(3,509	)
Net accumulated deferred income taxes	$	(5,160	)		$	(4,746	)		$	(3,913	)	$	(3,524	)

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The components of NextEra Energy's deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2010 are as follows:

	Amount			Expiration Dates
	(millions)
Net operating loss carryforwards:
Federal	$	484	(a)	2026 - 2030
State		170		2014 - 2030
Foreign		9		2021 - 2030
Net operating loss carryforwards	$	663
Tax credit carryforwards:
Federal	$	1,539	(b)	2022 - 2030
State		280		2011 - 2035
Net tax credit carryforwards	$	1,819

¾¾¾¾¾¾¾¾¾¾

(a)	Amount includes $42 million of tax carryforwards related to NextEra Energy's unrecognized tax benefits.
(b)	Amount is presented net of $52 million of tax carryforwards that are available to offset NextEra Energy's liability for unrecognized tax benefits.

The majority of the liabilities for unrecognized tax benefits represent tax positions for which the ultimate deductibility is highly certain but for which there is uncertainty about the timing of such deductibility.  A disallowance of the shorter deductibility period for these tax positions would not affect the annual effective income tax rate.  Included in the liabilities for unrecognized tax benefits at December 31, 2010 is approximately $6 million at NextEra Energy ($1 million at FPL) that, if disallowed, could impact the annual effective income tax rate.

NextEra Energy recognizes interest income (expense) related to unrecognized tax benefits (liabilities) in interest income and interest expense, respectively, net of the amount deferred at FPL.  At FPL, the offset to accrued interest receivable (payable) on income taxes is classified as a regulatory liability (regulatory asset) which will be amortized to income (expense) over a five-year period upon settlement in accordance with regulatory treatment.  At December 31, 2010 and 2009, NextEra Energy accrued approximately $135 million and $135 million for net interest receivable ($18 million and $38 million for FPL), respectively.  For the years ended December 31, 2010 and 2009, NextEra Energy recorded $(13) million and $9 million of interest.  Of this amount, $16 million and $13 million of interest income was recognized in NextEra Energy's consolidated statements of income and net deferred charges of $(29) million and $(4) million, respectively, were recognized in regulatory liabilities and regulatory assets on NextEra Energy's and FPL's consolidated balance sheets.

A reconciliation of unrecognized tax benefits is as follows:

	NextEra Energy									FPL
	2010			2009			2008			2010			2009			2008
	(millions)
Balance at beginning of year	$	279		$	249		$	320		$	247		$	217		$	281
Additions based on tax positions related to the current year		4			24			14			-			24			13
Reductions based on tax positions related to the current year		-			-			(44	)		-			-			(44	)
Additions for tax positions of the prior years		67			26			91			53			26			89
Reductions for tax positions of the prior years		(86	)		(20	)		(40	)		(85	)		(20	)		(30	)
Reductions relating to settlements with taxing authorities		-			-			(92	)		-			-			(92	)
Balance at end of year(a)		264			279			249			215			247			217
Tax carryforwards, deposits and other receivables		(259	)		(239	)		(219	)		(184	)		(192	)		(176	)
Balance at end of year, net	$	5		$	40		$	30		$	31		$	55		$	41

¾¾¾¾¾¾¾¾¾¾

(a)   Amounts are net of the federal tax benefit of state tax positions of approximately $15 million, $16 million and $14 million ($11 million, $12 million and $11 million for FPL), respectively.

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NextEra Energy and its subsidiaries file income tax returns in the U.S. federal jurisdiction and various states, the most significant of which is Florida, and certain foreign jurisdictions.  NextEra Energy and FPL are effectively no longer subject to U.S. federal, state and foreign examinations by taxing authorities for years before 2003.  NextEra Energy is in the process of finalizing a settlement with the Internal Revenue Service (IRS) with respect to the 1988 through 2005 tax years.  The settlement primarily relates to NextEra Energy’s and FPL’s method for certain deductions for repairs, casualty losses and indirect service costs.  This settlement is subject to the approval of the Joint Committee on Taxation.  Income tax returns for 2006, 2007 and 2008 are under examinat ion by the IRS.  The amounts of unrecognized tax benefits and related interest accruals may change within the next twelve months; however, NextEra Energy and FPL do not expect these changes to have a significant impact on NextEra Energy’s or FPL’s financial statements.

7.  Comprehensive Income

The components of NextEra Energy's comprehensive income and accumulated other comprehensive income (loss) are as follows:

			Accumulated Other Comprehensive Income (Loss)
	Net Income		Net Unrealized Gains (Losses) On Cash Flow Hedges			Other			Total			Comprehensive Income
	(millions)
Balances, December 31, 2007			$	(81	)	$	197		$	116
Net income of NextEra Energy	$	1,639											$	1,639
Net unrealized gains (losses) on cash flow hedges:
Effective portion of net unrealized gains				(4	)		-			(4	)			(4	)
Reclassification from AOCI to net income (net of $66 tax expense)				90			-			90				90
Net unrealized losses on available for sale securities (net of $30 tax benefit)				-			(46	)		(46	)			(46	)
Adjustments between AOCI and retained earnings				-			(1	)		(1	)			-
Defined benefit pension and other benefits plans (net of $104 tax benefit)				-			(168	)		(168	)			(167	)
Balances, December 31, 2008				5			(18	)		(13	)		$	1,512
Net income of NextEra Energy	$	1,615											$	1,615
Net unrealized gains (losses) on cash flow hedges:
Effective portion of net unrealized gains (net of $90 tax expense)				137			-			137				137
Reclassification from AOCI to net income (net of $50 tax benefit)(a)				(75	)		-			(75	)			(75	)
Net unrealized gains (losses) on available for sale securities:
Net unrealized gains on securities still held (net of $77 tax expense)				-			119			119				119
Reclassification from AOCI to net income (net of $17 tax benefit)				-			(27	)		(27	)			(27	)
Adjustments between AOCI and retained earnings				-			(5	)		(5	)			-
Defined benefit pension and other benefits plans (net of $14 tax expense)				-			22			22				22
Net unrealized gains on foreign currency translation (net of $5 tax expense)				-			11			11				11
Balances, December 31, 2009				67			102			169			$	1,802
Net income of NextEra Energy	$	1,957											$	1,957
Net unrealized gains (losses) on cash flow hedges:
Effective portion of net unrealized losses (net of $3 tax benefit)				(5	)		-			(5	)			(5	)
Reclassification from AOCI to net income (net of $35 tax benefit)				(38	)		-			(38	)			(38	)
Net unrealized gains (losses) on available for sale securities:
Net unrealized gains on securities still held (net of $41 tax expense)				-			60			60				60
Reclassification from AOCI to net income (net of $16 tax benefit)				-			(21	)		(21	)			(21	)
Defined benefit pension and other benefits plans (net of $1 tax expense)				-			2			2				2
Net unrealized losses on foreign currency translation				-			(1	)		(1	)			(1	)
Balances, December 31, 2010			$	24	(b)	$	142	(c)	$	166			$	1,954

¾¾¾¾¾¾¾¾¾¾

(a)	Includes amounts reclassified into earnings due to discontinuance of cash flow hedges of approximately $3 million (net of $2 million tax benefit) for which the hedged transactions are no longer probable of occurring.
(b)	Approximately $4 million of losses, related to derivative instruments, is expected to be reclassified into earnings within the next twelve months as either the hedged fuel is consumed, electricity is sold or principal and/or interest payments are made.  Such amount assumes no change in fuel prices, power prices,  interest rates or scheduled principal payments.
(c)	Approximately $1 million of prior service benefits and approximately $1 million of transition obligations is expected to be reclassified into earnings within the next twelve months.

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8.  Jointly-Owned Electric Plants

Certain NextEra Energy subsidiaries own undivided interests in the jointly-owned facilities described below, and are entitled to a proportionate share of the output from those facilities.  The subsidiaries are responsible for their share of the operating costs, as well as providing their own financing.  Accordingly, each subsidiary includes its proportionate share of the facilities and related revenues and expenses in the appropriate balance sheet and statement of income captions.  NextEra Energy's and FPL's respective shares of direct expenses for these facilities are included in fuel, purchased power and interchange, O&M expenses, depreciation and amortization expense and taxes other than income taxes and other on NextEra Energy's and FPL's consolidated statements of income.

NextEra Energy's and FPL's proportionate ownership interest in jointly-owned facilities is as follows:

	December 31, 2010
	Ownership Interest			Gross Investment(a)		Accumulated Depreciation(a)		Construction Work in Progress
			(millions)
FPL:
St. Lucie Unit No. 2	85	%		$	1,359	$	585	$	199
St. Johns River Power Park units and coal terminal	20	%		$	391	$	152	$	3
Scherer Unit No. 4	76	%		$	703	$	218	$	251
NextEra Energy Resources:
Duane Arnold	70	%		$	324	$	62	$	27
Seabrook	88.23	%		$	848	$	141	$	71
Wyman Station Unit No. 4	84.35	%		$	104	$	39	$	-
Corporate and Other:
Transmission substation assets located in Seabrook, New Hampshire	88.23	%		$	59	$	12	$	5

¾¾¾¾¾¾¾¾¾¾

(a)   Excludes nuclear fuel.

9.  Variable Interest Entities

As of December 31, 2010, NextEra Energy has eight 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 mi llion 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 approximately $200 million 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 secured by the storm-recovery property.  The bondholders have no recourse to the general credit of FPL.  The assets of the VIE were approximately $444 million at December 31, 2010 and consisted primarily of storm-recovery property, which is included in securitized storm-recovery costs on NextEra Energy's and FPL's consolidated balance sheets.  The liabilities of the VIE were approximately $542 million at December 31, 2010 and consisted primarily of storm-recovery bonds, which are included in long-term debt on NextEra Energy's and FPL's consolidated balance sheets.

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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 PPA effective in 1994 with this 250 mw coal-fired qualifying facility to purchase substantially all of the facility's capacity and electrical output over a substantial portion of its estimated useful life.  FPL absorbs a portion of the facility's variability related to changes in the market price of coal through the price it pays per mwh (energy payment).  After making exhaustive efforts, FPL was unable to obtain the information from the facility necessary to determine whether the facility is a VIE or whether FPL is the primary beneficiary of the facility.  The 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 years ended December 31, 2010, 2009 and 2008, FPL purchased 1,502,234 mwh, 1,604,735 mwh and 1,725,798 mwh, respectively, from the facility at a total cost of approximately $184 million, $173 million and $158 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.

In March 2010, FPL terminated its nuclear fuel lease agreements with a VIE from which it had previously leased nuclear fuel.  Upon termination of the lease agreements, FPL no longer consolidates the VIE since it no longer has a variable interest in the lessor.  Upon deconsolidation, FPL did not recognize any gain or loss and there was no significant effect on NextEra Energy’s and FPL’s consolidated balance sheets.

NextEra Energy Resources - NextEra Energy consolidates six NextEra Energy Resources’ VIEs.  NextEra Energy Resources is considered the primary beneficiary of these VIEs since NextEra Energy Resources 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.

Three of NextEra Energy Resources’ VIEs consolidate several entities which own and operate natural gas and/or oil electric generating facilities with the capability of producing a total of 1,285 mw.  These VIEs sell their electric output under power sales contracts to third parties, with expiration dates ranging from 2018 through 2022.  The power sales contracts provide the offtaker the ability to dispatch the facilities and require the offtaker to absorb the cost of fuel.  These VIEs use third party debt and equity to finance their 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 NextEra Energy Resources.  The assets and liabilities of these VI Es totaled approximately $829 million and $455 million, respectively, at December 31, 2010 and consisted primarily of property, plant and equipment and long-term debt.

The other three NextEra Energy Resources’ VIEs consolidate several entities which own and operate wind electric generating facilities with the capability of producing a total of 1,077 mw and an entity which owns and operates a 78 mile, 230 kilovolt transmission line.  These VIEs sell their electric output under power sales contracts to third parties with expiration dates ranging from 2018 through 2034.  The VIEs use both third-party debt and 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 as sets of these entities.  The debt holders have no recourse to the general credit of NextEra Energy Resources.  The assets and liabilities of these VIEs totaled approximately $1.7 billion and $1.6 billion, respectively, at December 31, 2010, and consisted primarily of property, plant and equipment, deferral related to differential membership interests and long-term debt.

Other - As of December 31, 2010, several NextEra Energy subsidiaries have investments totaling approximately $646 million ($480 million at FPL) in certain special purpose entities, which consisted primarily of investments in mortgage-backed securities.  These investments are included primarily in special use funds and other investments on NextEra Energy's consolidated balance sheets and in special use funds on FPL's consolidated balance sheets.  NextEra Energy is considered the primary beneficiary and therefore consolidates one of these entities with total assets of approximately $53 million.  NextEra Energy is considered the primary beneficiary of this entity because FPL and NextEra Energy Resources are equal investors and combined, are the ma jority investors in this entity and absorb substantially all of the expected losses and residual returns.  With respect to the other entities, NextEra Energy subsidiaries are not the primary beneficiary and therefore do not consolidate any of these entities because NextEra Energy subsidiaries 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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10.  Investments in Partnerships and Joint Ventures

NextEra Energy Resources- NextEra Energy Resources has non-controlling non-majority owned interests in various partnerships and joint ventures, essentially all of which own electric generating facilities.  At December 31, 2010 and 2009, NextEra Energy Resources' investments in partnerships and joint ventures totaled approximately $217 million and $173 million, respectively, which is included in other investments on NextEra Energy's consolidated balance sheets.  NextEra Energy Resources' interest in these partnerships and joint ventures range from approximately 5.5% to 50%.  At December 31, 2010, the principal operating entities included in NextEra Energy Resources' investments in p artnerships and joint ventures were Northeast Energy, LP, Mojave 3/4/5, Luz Solar Partners Ltd., III, Luz Solar Partners Ltd., IV and Luz Solar Partners Ltd., V and in 2009 also included Mojave 16/17/18 LLC.

Summarized combined information for these principal operating entities is as follows:

	2010			2009
	(millions)
Net income	$	81		$	78
Total assets	$	660		$	717
Total liabilities	$	210		$	354
Partners'/members' equity	$	450		$	363
NextEra Energy Resources' share of underlying equity in the principal operating entities	$	223		$	180
Difference between investment carrying amount and underlying equity in net assets(a)		(26	)		(15	)
NextEra Energy Resources' investment carrying amount for the principal operating entities	$	197		$	165

¾¾¾¾¾¾¾¾¾¾

(a)   The majority of the difference between the investment carrying amount and the underlying equity in net assets is being amortized over the remaining life of the investee's assets.

Certain subsidiaries of NextEra Energy Resources provide services to the partnerships and joint ventures, including operations and maintenance and business management services.  NextEra Energy's operating revenues for the years ended December 31, 2010, 2009 and 2008 include approximately $25 million, $21 million and $21 million, respectively, related to such services.  The net receivables at December 31, 2010 and 2009, for these services, as well as for affiliate energy commodity transactions, payroll and other payments made on behalf of these investees, were approximately $36 million and $29 million, respectively, and are included in other receivables on NextEra Energy's consolidated balance sheets.

NextEra Energy - In 2004, a trust created by NextEra Energy sold $300 million of 5 7/8% preferred trust securities to the public and $9 million of common trust securities to NextEra Energy.  The trust is an unconsolidated 100%-owned finance subsidiary.  The proceeds from the sale of the preferred and common trust securities were used to buy 5 7/8% junior subordinated debentures maturing in March 2044 from Capital Holdings.  NextEra Energy has fully and unconditionally guaranteed the preferred trust securities and the junior subordinated debentures.

11.  Common and Preferred Stock

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

	Years Ended December 31,
	2010		2009		2008
	(millions, except per share amounts)
Numerator - net income	$	1,957	$	1,615	$	1,639
Denominator:
Weighted-average number of common shares outstanding - basic		410.3		404.4		400.1
Options, performance share awards, restricted stock, equity units and warrants(a)		2.7		2.8		2.6
Weighted-average number of common shares outstanding - assuming dilution		413.0		407.2		402.7
Earnings per share of common stock:
Basic	$	4.77	$	3.99	$	4.10
Assuming dilution	$	4.74	$	3.97	$	4.07

¾¾¾¾¾¾¾¾¾¾

(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.  Options, performance share awards, restricted stock, equity units and warrants 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, restricted stock and performance share awards which were not included in the denominator above due to their antidilutive effect were approximately 9.1 million, 0.8 million and 0.5 million for the years ended December 31, 2010, 2009 and 2008, respectively.

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Common Stock Dividend Restrictions - NextEra Energy's charter does not limit the dividends that may be paid on its common stock.  FPL's mortgage securing FPL's first mortgage bonds contains provisions which, under certain conditions, restrict the payment of dividends and other distributions to NextEra Energy.  These restrictions do not currently limit FPL's ability to pay dividends to NextEra Energy.

Employee Stock Ownership Plan - The employee retirement savings plans of NextEra Energy include a leveraged ESOP feature.  Shares of common stock held by the trust for the employee retirement savings plans (Trust) are used to provide all or a portion of the employers' matching contributions.  Dividends received on all shares, along with cash contributions from the employers, are used to pay principal and interest on an ESOP loan held by a subsidiary of Capital Holdings.  Dividends on shares allocated to employee accounts and used by the Trust for debt service are replaced with shares of common stock, at prevailing market prices, in an equivalent amount.  For purposes of computing basic and fully diluted earnings per share, ESOP shares that have been committed to be released are considered outstanding.

ESOP-related compensation expense of approximately $37 million, $42 million and $40 million in 2010, 2009 and 2008, respectively, was recognized based on the fair value of shares allocated to employee accounts during the period.  Interest income on the ESOP loan is eliminated in consolidation.  ESOP-related unearned compensation included as a reduction of common shareholders' equity at December 31, 2010 was approximately $69 million, representing unallocated shares at the original issue price.  The fair value of the ESOP-related unearned compensation account using the closing price of NextEra Energy common stock at December 31, 2010 was approximately $248 million.

Stock-Based Compensation - Net income for the years ended December 31, 2010, 2009 and 2008 includes approximately $57 million, $51 million and $47 million, respectively, of compensation costs and $22 million, $20 million and $18 million, respectively, of income tax benefits related to stock-based compensation arrangements.  Compensation cost capitalized for the years ended December 31, 2010, 2009 and 2008 was not material.  As of December 31, 2010, there were approximately $63 million of unrecognized compensation costs related to nonvested/nonexercisable stock-based compensation arrangements.  These costs are expected to be recognized over a weighted-average period of 1.9 years.

At December 31, 2010, approximately 26 million shares of common stock were authorized and approximately 11 million were available for awards (including outstanding awards) to officers, employees and non-employee directors of NextEra Energy and its subsidiaries under NextEra Energy's amended and restated long-term incentive plan and non-employee directors stock plans.  NextEra Energy satisfies restricted stock and performance share awards by issuing new shares of its common stock or by purchasing shares of its common stock in the open market.  NextEra Energy satisfies stock option exercises by issuing new shares of its common stock and generally grants most of its stock options in the first quarter of each year.

Restricted Stock and Performance Share Awards- Restricted stock typically vests within three years after the date of grant and is subject to, among other things, restrictions on transferability prior to vesting.  The fair value of restricted stock is measured based upon the closing market price of NextEra Energy common stock as of the date of grant.  Performance share awards are typically payable at the end of a three-year performance period if the specified performance criteria are met.  The fair value of performance share awards is estimated based upon the closing market price of NextEra Energy common stock as of the date of grant less the present value of expected dividends, multiplied by an estimated performance multiple determined on the basis of historical experience, which is subsequently trued up based on actual performance.

The activity in restricted stock and performance share awards for the year ended December 31, 2010 was as follows:

	Shares		Weighted-Average Grant Date Fair Value Per Share
Restricted Stock:
Nonvested balance, January 1, 2010	1,143,282			$	55.55
Granted	607,000			$	46.72
Vested	(523,365	)		$	57.42
Forfeited	(72,327	)		$	50.21
Nonvested balance, December 31, 2010	1,154,590			$	50.40
Performance Share Awards:
Nonvested balance, January 1, 2010	1,157,343			$	51.20
Granted	717,590			$	42.95
Vested	(465,780	)		$	53.97
Forfeited	(90,755	)		$	48.26
Nonvested balance, December 31, 2010	1,318,398			$	45.96

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The weighted-average grant date fair value per share of restricted stock granted for the years ended December 31, 2009 and 2008 was $51.50 and $62.66, respectively.  The weighted-average grant date fair value per share of performance share awards granted for the years ended December 31, 2009 and 2008 was $42.66 and $51.48, respectively.

The total fair value of restricted stock and performance share awards vested was $47 million, $46 million and $64 million for the years ended December 31, 2010, 2009 and 2008, respectively.

Options - Options typically vest within three years after the date of grant and have a maximum term of ten years.  The exercise price of each option granted equals the closing market price of NextEra Energy common stock on the date of grant.  The fair value of the options is estimated on the date of the grant using the Black-Scholes option-pricing model and based on the following assumptions:

	2010		2009		2008
Expected volatility(a)	20.74 - 21.64	%	19.02 - 20.23	%	17.33	%
Expected dividends	3.61 - 4.39	%	3.35 - 3.71	%	2.75	%
Expected term (years)	6	(b)	6	(b)	6	(c)
Risk-free rate	1.65 - 2.91	%	2.68 - 2.97	%	3.24	%

¾¾¾¾¾¾¾¾¾¾

(a)	Based on historical experience.
(b)	Based on historical exercise and post-vesting cancellation experience adjusted for outstanding awards.
(c)	NextEra Energy used the "simplified" method to calculate the expected term.

Option activity for the year ended December 31, 2010 was as follows:

	Shares Underlying Options		Weighted- Average Exercise Price Per Share		Weighted- Average Remaining Contractual Term (years)		Aggregate Intrinsic Value (millions)
Balance, January 1, 2010	5,739,263		$	35.65
Granted	687,001		$	45.71
Exercised	(1,384,015	)	$	29.52
Forfeited	(3,197	)	$	64.69
Expired	(2,400	)	$	25.27
Balance, December 31, 2010	5,036,652		$	38.69		4.4	$	73
Exercisable, December 31, 2010	3,942,358		$	35.85		3.2	$	68

The weighted-average grant date fair value of options granted was $6.22, $6.79 and $9.90 per share for the years ended December 31, 2010, 2009 and 2008, respectively.  The total intrinsic value of stock options exercised was approximately $32 million, $9 million and $17 million for the years ended December 31, 2010, 2009 and 2008, respectively.

Cash received from option exercises was approximately $41 million, $10 million and $14 million for the years ended December 31, 2010, 2009 and 2008, respectively.  The tax benefits realized from options exercised were approximately $12 million, $3 million and $6 million for the years ended December 31, 2010, 2009 and 2008, respectively.

Continuous Offering of NextEra Energy Common Stock - In December 2010, NextEra Energy completed the program it commenced in January 2009 under which it offered and sold, from time to time, NextEra Energy common stock having a gross sales price of up to $400 million.  During 2010 and 2009, NextEra Energy received gross proceeds through the sale and issuance of common stock under this program of approximately $240 million and $160 million, respectively.

Preferred Stock - NextEra Energy's charter authorizes the issuance of 100 million shares of serial preferred stock, $0.01 par value, none of which are outstanding.  FPL's charter authorizes the issuance of 10,414,100 shares of preferred stock, $100 par value; 5 million shares of subordinated preferred stock, no par value and 5 million shares of preferred stock, no par value, none of which are outstanding.

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12.  Debt

Long-term debt consists of the following:

	December 31,
	2010			2009
	(millions)
FPL:
First mortgage bonds - maturing 2013 through 2041 - 4.85% to 6.20%	$	5,540		$	4,640
Storm-recovery bonds - maturing 2013 through 2021 - 5.0440% to 5.2555%(a)		531			572
Pollution control, solid waste disposal and industrial development revenue bonds - maturing 2020 through 2029 - variable, 0.3% and 0.2% weighted-average interest rates, respectively(b)		633			633
Other long-term debt - maturing 2011 through 2040 - 4.000% to 5.250%		57			24
Unamortized discount		(34	)		(33	)
Total long-term debt of FPL		6,727			5,836
Less current maturities of long-term debt		45			42
Long-term debt of FPL, excluding current maturities		6,682			5,794
Capital Holdings:
Debentures - maturing 2011 through 2019 - 2.55% to 7 7/8%		2,500			1,850
Debentures - maturing 2011 through 2012 - variable, 1.0% and 0.9% weighted-average interest rate, respectively(c)(d)		450			450
Debentures, related to NextEra Energy's equity units - maturing 2014 and 2015 - 3.60% and 1.90%		753			350
Junior Subordinated Debentures - maturing 2044 through 2069 - 5 7/8% to 8.75%		2,353			2,353
Senior secured bonds - maturing 2030 - 7.500%(e)		500			500
Japanese yen denominated senior notes - maturing 2030 - 5.1325%(d)		123			-
Japanese yen denominated term loans - maturing 2011 - variable, 2.2% and 3.3% weighted-average interest rate, respectively(c)(d)		327			287
Term loans - maturing 2011 through 2014 - variable, 1.2% and 1.0% weighted-average interest rate, respectively(c)		950			910
Fair value swap		3			14
Unamortized discount		(8	)		(3	)
Total long-term debt of Capital Holdings		7,951			6,711
Less current maturities of long-term debt		1,485			200
Long-term debt of Capital Holdings, excluding current maturities		6,466			6,511
NextEra Energy Resources:
Senior secured limited recourse bonds and notes - maturing 2013 through 2037 - 5.608% to 7.59%		2,652			2,488
Other long-term debt - maturing 2012 through 2028 - primarily limited recourse and variable, 2.6% and 2.4% weighted-average interest rates, respectively(c)(d)		2,521			1,833
Canadian revolving credit facility - maturing 2013 - variable, 1.3%(c)		82			-
Unamortized premium		-			1
Total long-term debt of NextEra Energy Resources		5,255			4,322
Less current maturities of long-term debt		390			327
Long-term debt of NextEra Energy Resources, excluding current maturities		4,865			3,995
Total long-term debt	$	18,013		$	16,300

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(a)	Principal on the storm-recovery bonds is due on the final maturity date (the date by which the principal must be repaid to prevent a default) for each tranche, however, it began being paid semiannually and sequentially on February 1, 2008, when the first semiannual interest payment became due.
(b)	Tax exempt bonds that permit individual bond holders to tender the bonds for purchase at any time prior to maturity.  In the event bonds are tendered for purchase, they would be remarketed by a designated remarketing agent in accordance with the related indenture.  If the remarketing is unsuccessful, FPL would be required to purchase the tax exempt bonds.  As of December 31, 2010, all tax exempt bonds tendered for purchase have been successfully remarketed.  FPL's bank revolving lines of credit are available to support the purchase of tax exempt bonds.
(c)	Variable rate is based on an underlying index plus a margin.
(d)	Interest rate swap agreements have been entered into for the majority of these debt issuances.
(e)	Issued by a wholly-owned subsidiary of Capital Holdings and collateralized by a third-party note receivable held by that subsidiary.  See Note 5.

Minimum annual maturities of long-term debt for NextEra Energy are approximately $1,920 million, $816 million, $1,816 million, $940 million and $1,814 million for 2011, 2012, 2013, 2014 and 2015, respectively.  The respective amounts for FPL are approximately $45 million, $50 million, $453 million, $56 million and $60 million.

At December 31, 2010 and 2009, commercial paper borrowings had a weighted-average interest rate of 0.39% (0.26% for FPL) and 0.19% (0.19% for FPL), respectively.  Available lines of credit aggregated approximately $7.4 billion ($4.4 billion for Capital Holdings and $3.0 billion for FPL) at December 31, 2010 and were available to support Capital Holdings' and FPL's commercial paper programs.  These facilities provide for the issuance of letters of credit of up to approximately $6.4 billion.  The issuance of letters of credit is subject to the aggregate commitment under the applicable facility.  While no direct borrowings were outstanding at December 31, 2010, letters of credit totaling $771 million and $8 million were outstanding under the Capital Holdings and FPL credit facilities , respectively.

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NextEra Energy has guaranteed certain payment obligations of Capital Holdings, including most of those under Capital Holdings' debt, including all of its debentures and commercial paper issuances, as well as most of its guarantees.  Capital Holdings has guaranteed certain debt and other obligations of NextEra Energy Resources and its subsidiaries.

In 2008, FPL entered into a reclaimed water agreement with Palm Beach County, Florida (PBC) to provide FPL's WCEC with reclaimed water for cooling purposes beginning in January 2011.  Under the reclaimed water agreement, FPL is to construct a reclaimed water system, including modifications to an existing treatment plant and a water pipeline, that PBC will legally own and operate.  The reclaimed water agreement also requires PBC to issue bonds for the purpose of paying the costs associated with the construction of the reclaimed water system.  In 2009, PBC issued approximately $68 million principal amount of Palm Beach County, Florida Water and Sewer Revenue Bonds.  Under the reclaimed water agreement, FPL will pay PBC an operating fee for the reclaimed water delivered which will be used by PBC to , among other things, service the principal of, and interest on, the bonds.  The portion of the operating fee related to PBC's servicing principal of, and interest on, the bonds will be paid by FPL, beginning October 2011, until final maturity of the bonds.  FPL does not have a direct obligation to the bondholders; however, if FPL or PBC were to terminate the reclaimed water agreement, FPL would be obligated to continue to pay the portion of the operating fee intended to reimburse PBC for costs related to issuance of the bonds, including amounts to be used by PBC to service the principal of, and interest on, the bonds.  In the event of a default by PBC under the reclaimed water agreement, FPL would have certain rights, including, among other things, the right to appoint a third-party contractor to repair, and restore operations of, the reclaimed water treatment plant, and, in the event of a termination of the reclaimed water agreement by FPL relating to a PBC default, the right to assume ownership of the reclaimed water pipeline from PBC.  For financial reporting purposes, FPL is considered the owner of the reclaimed water system and FPL and NextEra Energy are recording electric utility plant in service and other property as costs are incurred and long-term debt (see FPL's other long-term debt in the table above) as costs are eligible for reimbursement by PBC to FPL.

In 2009, NextEra Energy sold $350 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 NextEra Energy common stock (stock purchase contract) and, initially, a 1/20, or 5%, undivided beneficial ownership interest in a Series C Debenture due June 1, 2014 issued in the principal amount of $1,000 by Capital Holdings (see table above).  Each stock purchase contract requires the holder to purchase by no later than June 1, 2012 (the final settlement date) for a price of $50 in cash, a number of shares of NextEra Energy common stock (subject to antidilution adjustments) based on a price per share range of $55.67 to $66.80.  If purchased on the final settlement date, as of December 31, 2010, the number of shares issued would (subject to antidilution adjustments) range from 0.9000 shares if the applicable market value of a share of common stock is less than or equal to $55.67, to 0.7501 shares if the applicable market value of a share is equal to or greater than $66.80, with applicable market value to be determined using the average closing prices of NextEra Energy common stock over a 20-day trading period ending May 29, 2012.  Total annual distributions on the equity units will be at the rate of 8.375%, consisting of interest on the debentures (3.60% per year) and payments under the stock purchase contracts (4.775% per year).  The interest rate on the debentures is expected to be reset on or after December 1, 2011.  The holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the Capital Holding debentures that are part of its equity unit.  The undivided beneficial ownership interest in the Capital Holdings debenture tha t is a component of each Corporate Unit is pledged to NextEra Energy to secure the holder’s obligation to purchase NextEra Energy 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 NextEra Energy of its intention to settle the stock purchase contract with cash, NextEra Energy would exercise its rights as a secured party in the debentures to satisfy in full the holders’ obligations to purchase NextEra Energy common stock under the related stock purchase contracts on the final settlement date.  The debentures are fully and unconditionally guaranteed by NextEra Energy.

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In 2010, NextEra Energy sold $402.5 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 NextEra Energy common stock (stock purchase contract) and, initially, a 1/20, or 5%, undivided beneficial ownership interest in a Series D Debenture due September 1, 2015 issued in the principal amount of $1,000 by Capital Holdings (see table above).  Each stock purchase contract requires the holder to purchase by no later than September 1, 2013 (the final settlement date) for a price of $50 in cash, a number of shares of NextEra Energy common stock (subject to antidilution adjustments) based on a price per share range of $55.02 to $68.78.  If purchased on the final settlement date, as of December 31, 2010, the number of shares issued would (subject to antidilution adjustments) range from 0.9088 shares if the applicable market value of a share of common stock is less than or equal to $55.02, to 0.7270 shares if the applicable market value of a share is equal to or greater than $68.78, with applicable market value to be determined using the average closing prices of NextEra Energy common stock over a 20-day trading period ending August 28, 2013.  Total annual distributions on the equity units will be at the rate of 7.00%, consisting of interest on the debentures (1.90% per year) and payments under the stock purchase contracts (5.10% per year).  The interest rate on the debentures is expected to be reset on or after March 1, 2013.  The holder of an equity unit may satisfy its purchase obligation with proceeds raised from remarketing the Capital Holdings debentures that are part of its equity unit.  The undivided beneficial ownership interest in the Capital Holdin gs debenture that is a component of each Corporate Unit is pledged to NextEra Energy to secure the holder’s obligation to purchase NextEra Energy 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 NextEra Energy of its intention to settle the stock purchase contract with cash, NextEra Energy would exercise its rights as a secured party in the debentures to satisfy in full the holders’ obligations to purchase NextEra Energy common stock under the related stock purchase contracts on the final settlement date.  The debentures are fully and unconditionally guaranteed by NextEra Energy.

Prior to the issuance of NextEra Energy’s common stock, the stock purchase contracts will be reflected in NextEra Energy’s diluted earnings per share calculations using the treasury stock method.  Under this method, the number of shares of NextEra Energy common stock used in calculating diluted earnings per share is deemed to be increased by the excess, if any, of the number of shares that would be issued upon settlement of the stock purchase contracts over the number of shares that could be purchased by NextEra Energy in the market, at the average market price during the period, using the proceeds receivable upon settlement.

13.  Asset Retirement Obligations

FPL's ARO relates primarily to the nuclear decommissioning obligation of its nuclear units.  FPL's AROs other than nuclear decommissioning are not significant.  The accounting provisions result in timing differences in the recognition of legal asset retirement costs for financial reporting purposes and the method the FPSC allows FPL to recover in rates.  NextEra Energy Resources' ARO relates primarily to the nuclear decommissioning obligation of its nuclear plants and obligations for the dismantlement of its wind facilities located on leased property.  See Note 1 - Decommissioning of Nuclear Plants, Dismantlements of Plants and Other Accrued Asset Removal Costs.

A rollforward of NextEra Energy's and FPL's ARO is as follows:

	FPL			NextEra Energy Resources			NextEra Energy
				(millions)
Balance, December 31, 2008	$	1,743		$	540		$	2,283
Liabilities incurred		-			4			4
Accretion expense		96			36			132
Revision in estimated cash flows - net		(6	)		5			(1	)
Balance, December 31, 2009		1,833			585			2,418
Liabilities incurred		-			3			3
Accretion expense		101			36			137
Liabilities settled		-			(1	)		(1	)
Revision in estimated cash flows - net		(851	)(a)		(67	)(b)		(918	)
Balance, December 31, 2010	$	1,083		$	556		$	1,639

¾¾¾¾¾¾¾¾¾¾¾¾¾

(a)	Primarily reflects the effect of a decrease in the escalation rates used to determine the ultimate projected costs of decommissioning FPL's nuclear units and lower costs due to the expected future reimbursement by the DOE of certain spent fuel storage costs as stipulated by a spent fuel settlement agreement.
(b)	Primarily reflects the effect of revised probability assessments regarding when assets will be retired and ultimately decommissioned and lower costs due to the expected future reimbursement by the DOE of certain spent fuel storage costs as stipulated by a spent fuel settlement agreement.

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Restricted funds for the payment of future expenditures to decommission NextEra Energy's and FPL's nuclear units included in special use funds on NextEra Energy's and FPL's consolidated balance sheets are as follows (see Note 5):

	FPL		NextEra Energy Resources		NextEra Energy
			(millions)
Balance, December 31, 2010	$	2,512	$	1,105	$	3,617
Balance, December 31, 2009	$	2,285	$	982	$	3,267

NextEra Energy and FPL have identified but not recognized ARO liabilities related to electric transmission and distribution and telecommunications assets resulting from easements over property not owned by NextEra Energy or FPL.  In addition, NextEra Energy has identified but not recognized ARO liabilities related to the majority of NextEra Energy Resources' hydro facilities.  These easements are generally perpetual and, along with the hydro facilities, only require retirement action upon abandonment or cessation of use of the property or facility for its specified purpose.  The ARO liability is not estimable for such easements and hydro facilities as NextEra Energy and FPL intend to use these properties and facilities indefinitely.  In the event NextEra Energy and FPL decide to abandon or cease the use of a particular easement and/or hydro facility, an ARO liability would be recorded at that time.

14.  Commitments and Contingencies

Commitments - NextEra Energy 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 NextEra Energy Resources, 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 include the cost for construction of a transmission line in Texas and FPL FiberNet, LLC's (FPL FiberNet) costs to meet customer-specific requirements and maintain its fiber-optic network.

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At December 31, 2010, estimated planned capital expenditures for 2011 through 2015 were as follows:

	2011		2012		2013		2014		2015		Total
	(millions)
FPL:
Generation:(a)
New(b)(c)	$	1,520	$	1,870	$	500	$	105	$	-	$	3,995
Existing		655		570		610		665		490		2,990
Transmission and distribution		720		870		820		760		840		4,010
Nuclear fuel		260		170		255		205		220		1,110
General and other		120		145		95		120		105		585
Total	$	3,275	$	3,625	$	2,280	$	1,855	$	1,655	$	12,690
NextEra Energy Resources:
Wind(d)	$	505	$	30	$	10	$	5	$	-	$	550
Solar(e)		955		885		420		75		-		2,335
Nuclear(f)		585		275		250		250		265		1,625
Natural gas		140		35		65		40		120		400
Other(g)		85		75		50		60		50		320
Total	$	2,270	$	1,300	$	795	$	430	$	435	$	5,230
Corporate and Other(h)	$	400	$	490	$	70	$	30	$	30	$	1,020

¾¾¾¾¾¾¾¾¾¾

(a)	Includes AFUDC of approximately $49 million, $76 million, $79 million, $29 million and $3 million in 2011 to 2015, respectively.
(b)	Includes land, generating structures, transmission interconnection and integration and licensing.
(c)	Includes 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 $98 million, $75 million and $24 million in 2011 to 2013, 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 that have received applicable internal approvals and related transmission.  NextEra Energy Resources plans to add new wind generation of approximately 3,500 mw to 5,000 mw in 2010 through 2014, including 754 mw added in 2010 and approximately 700 mw to 1,000 mw in 2011, at a total cost of approximately $7 billion to $10 billion.
(e)	Consists of capital expenditures for planned new solar projects that have received applicable internal approvals and related transmission.  NextEra Energy Resources plans to add new solar generation of approximately 400 mw to 600 mw in 2010 through 2014, including 5 mw added in 2010, at a total cost of approximately $3 billion to $4 billion.
(f)	Includes nuclear fuel.
(g)	Consists of capital expenditures that have received applicable internal approvals.  NextEra Energy Resources plans to add natural gas infrastructure projects totaling approximately $400 million to $600 million in 2010 through 2014.
(h)	Consists of capital expenditures that have received applicable internal approvals and includes AFUDC of approximately $9 million, $41 million and $18 million in 2011 to 2013, respectively.

NextEra Energy has guaranteed certain payment obligations of Capital Holdings, including most payment obligations under Capital Holdings' debt and guarantees.  Additionally, at December 31, 2010, subsidiaries of NextEra Energy, other than FPL, in the normal course of business, have guaranteed certain debt service and fuel payments of non-consolidated entities of NextEra Energy Resources.  The terms of the guarantees relating to the non-consolidated entities are equal to the terms of the related agreements/contracts, with remaining terms ranging from less than one year to seven years.  The maximum potential amount of future payments that could be required under these guarantees at December 31, 2010 was approximately $34 million.  At December 31, 2010, NextEra Energy did not have an y liabilities recorded for these guarantees.  In certain instances, NextEra Energy can seek recourse from third parties for amounts paid under the guarantees.  At December 31, 2010, the fair value of these guarantees was not material.

Contracts - In addition to the estimated planned 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 650 mw from certain cogenerators and small power producers (qualifying facilities) with expiration dates ranging from 2024 through 2032.  The purchased power contracts provide for capacity and energy payments.  Energy payments are based o n 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 one agreement with an electricity supplier to purchase approximately 155 mw of power with an expiration date of 2012.  In general, the agreement requires FPL to make a capacity payment and supply the fuel consumed by the plant under the contract.  FPL has contracts with expiration dates through 2036 for the purchase and transportation of natural gas and coal, and storage of natural gas.

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NextEra Energy Resources 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 April 2011 through 2031, approximately $1.1 billion of which is included in the estimated planned capital expenditures table in Commitments above.  In addition, NextEra Energy Resources has contracts primarily for the purchase, transportation and storage of natural gas and firm transmission service with expiration dates ranging from March 2011 through 2033.

The required capacity and/or minimum payments under the contracts discussed above as of December 31, 2010 were estimated as follows:

	2011		2012		2013		2014		2015		Thereafter
FPL:	(millions)
Capacity payments:(a)
Qualifying facilities	$	270	$	290	$	270	$	275	$	280	$	2,605
JEA and Southern subsidiaries	$	210	$	210	$	205	$	185	$	160	$	195
Other electricity suppliers	$	10	$	5	$	-	$	-	$	-	$	-
Minimum payments, at projected prices:
Natural gas, including transportation and storage(b)	$	2,185	$	1,130	$	575	$	570	$	550	$	7,470
Oil(b)	$	150	$	-	$	-	$	-	$	-	$	-
Coal(b)	$	90	$	70	$	60	$	5	$	-	$	-
NextEra Energy Resources(c)	$	1,250	$	225	$	180	$	165	$	165	$	830

¾¾¾¾¾¾¾¾¾¾

(a)	Capacity payments under these contracts, substantially all of which are recoverable through the capacity clause, totaled approximately $537 million, $603 million and $584 million for the years ended December 31, 2010, 2009 and 2008, respectively.  Energy payments under these contracts, which are recoverable through the fuel clause, totaled approximately $434 million, $439 million and $510 million for the years ended December 31, 2010, 2009 and 2008, respectively.
(b)	Recoverable through the fuel clause.
(c)	Includes termination payments associated with wind turbine contracts for projects that have not yet received applicable internal approvals.

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, NextEra Energy 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, NextEra Energy 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.  NextEra Energy 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 $14 million, $35 million and $18 million, plus any applicable taxes, per incident, respectively.

NextEra Energy participates in nuclear insurance mutual companies that provide $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.  NextEra Energy 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 NextEra Energy's or another participating insured's nuclear plants, NextEra Energy could be assessed up to $164 million ($95 million for FPL), plus any applicable taxes, in retrospective premiums in a policy year.  NextEra Energy 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 $3 million, plus any applicable taxes, respectively.

Due to the high cost and limited coverage available from third-party insurers, NextEra Energy 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 located throughout Florida.  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 (see Note 1 - Revenues and Rates) 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 NextEra Energy and FPL and could have a material adverse effect on NextEra Energy's and FPL's financial condition and results of operations.

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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 c ontrol 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 of up to $25,000 per day for each violation from an unspecified date after June 1, 1975 through January 30, 1997.  The EPA has made revisions to its civil penalty rule such that the maximum penalty is $27,500 per day for each violation from January 31, 1997 through March 15, 2004, $32,500 per day for each violation from March 16, 2004 through January 12, 2009 and $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, den ying 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, NextEra Energy, 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 NextEra Energy 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.  NextEra Energy has filed an answer to the complaint.  NextEra Energy 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 NextEra Energy, 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 case is in discovery and has been scheduled for trial in September 2011.

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 (NextEra Energy Resources 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 NextEra Energy Resources Affiliates had contractual obligations to produce and sell to TXU a minimum quantity of renewable energy credits each year during the period from 2002 through 2005 and that the NextEra Energy Resources Affiliates failed to meet this obligation.  The plaintiff asserted claims for breach of contract and declaratory judgment and sought damages of approximately $34 million.  Following a jury trial in 2007, among other findings, both TXU and the NextEra Energy Resources 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 has remanded the case back to the trial court for further proceedings to determine the amount of damages payable by the NextEra Energy Resources Affiliates.  The NextEra Energy Resources Affiliates filed a motion for rehearing of the appellate court’s decision, wh ich motion was denied, and will appeal the appellate court decision to the Texas Supreme Court.

NextEra Energy 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, NextEra Energy 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 NextEra Energy 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 NextEra Energy or FPL.  In the event that NextEra Energy 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 advers e 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 NextEra Energy or FPL.

106

15.  Segment Information

NextEra Energy's reportable segments are FPL, a rate-regulated utility, and NextEra Energy Resources, a competitive energy business.  Beginning in 2010, NextEra Energy Resources' segment information includes an allocation of interest expense from Capital Holdings based on a deemed capital structure of 70% debt and allocated shared service costs.  These changes were made to reflect an expected average capital structure at Capital Holdings and more accurately reflect NextEra Energy Resources' operating costs.  Corporate and Other represents other business activities, other segments that are not separately reportable and eliminating entries.  NextEra Energy's operating revenues derived from the sale of electricity represented approximately 95%, 98% and 96% of NextEra Energy's operating revenues for the years ended December 31, 2010, 2009 and 2008.  Less than 1% of operating revenues were from foreign sources for each of the three years ended December 31, 2010, 2009 and 2008.  At December 31, 2010 and 2009, approximately 1% of long-lived assets were located in foreign countries.

NextEra Energy's segment information is as follows:

	2010										2009									2008
	FPL		NextEra Energy Resources(a)			Corp. and Other			Total		FPL		NextEra Energy Resources(a)(c)			Corp. and Other(c)		Total		FPL		NextEra Energy Resources(a)(c)		Corp. and Other(c)			Total
											(millions)
Operating revenues	$	10,485	$	4,636		$	196		$	15,317	$	11,491	$	3,997		$	155	$	15,643	$	11,649	$	4,570	$	191		$	16,410
Operating expenses	$	8,636	$	3,286		$	152		$	12,074	$	9,910	$	3,024		$	115	$	13,049	$	10,120	$	3,305	$	160		$	13,585
Interest expense	$	361	$	515		$	103		$	979	$	318	$	460		$	71	$	849	$	334	$	418	$	61		$	813
Interest income	$	-	$	21		$	70		$	91	$	1	$	23		$	54	$	78	$	11	$	27	$	34		$	72
Depreciation and amortization	$	1,008	$	778		$	21		$	1,807	$	1,097	$	651		$	17	$	1,765	$	860	$	565	$	17		$	1,442
Equity in earnings of equity method investees	$	-	$	58		$	-		$	58	$	-	$	52		$	-	$	52	$	-	$	93	$	-		$	93
Income tax expense (benefit)(b)	$	580	$	(11	)	$	(37	)	$	532	$	473	$	(158	)	$	12	$	327	$	443	$	27	$	(20	)	$	450
Net income (loss)	$	945	$	980		$	32		$	1,957	$	831	$	759		$	25	$	1,615	$	789	$	831	$	19		$	1,639
Capital expenditures, independent power and other investments and nuclear fuel purchases	$	2,706	$	3,072		$	68		$	5,846	$	2,717	$	3,235		$	54	$	6,006	$	2,367	$	2,829	$	40		$	5,236
Property, plant and equipment	$	32,423	$	21,304		$	494		$	54,221	$	30,982	$	18,844		$	343	$	50,169	$	28,972	$	16,268	$	288		$	45,528
Accumulated depreciation and amortization	$	10,871	$	4,073		$	202		$	15,146	$	10,578	$	3,341		$	172	$	14,091	$	10,189	$	2,771	$	157		$	13,117
Total assets	$	28,698	$	22,389		$	1,907		$	52,994	$	26,812	$	20,136		$	1,510	$	48,458	$	26,175	$	17,157	$	1,489		$	44,821
Investment in equity method investees	$	-	$	217		$	10		$	227	$	-	$	173		$	10	$	183	$	-	$	189	$	9		$	198

¾¾¾¾¾¾¾¾¾¾¾¾

(a)	Interest expense allocated from Capital Holdings to NextEra Energy Resources is based on a deemed capital structure of 70% debt.  For this purpose, the deferred credit associated with differential membership interests sold by NextEra Energy Resources' subsidiaries is included with debt.  Residual non-utility interest expense is included in Corporate and Other.
(b)	NextEra Energy Resources' tax expense (benefit) includes PTCs that were recognized based on its tax sharing agreement with NextEra Energy.  See Note 1 - Income Taxes.
(c)	Segment information restated for the changes discussed above.

107

16.  Summarized Financial Information of Capital Holdings

Capital Holdings, a 100% owned subsidiary of NextEra Energy, provides funding for and holds ownership interests in NextEra Energy's operating subsidiaries other than FPL.  Most of Capital Holdings' debt, including its debentures, and payment guarantees are fully and unconditionally guaranteed by NextEra Energy.  Condensed consolidating financial information is as follows:

Condensed Consolidating Statements of Income

	Year Ended December 31, 2010												Year Ended December 31, 2009												Year Ended December 31, 2008
	NextEra Energy (Guaran- tor)			Capital Holdings			Other(a)			NextEra Energy Consoli- dated			NextEra Energy (Guaran- tor)			Capital Holdings			Other(a)			NextEra Energy Consoli- dated			NextEra Energy (Guaran- tor)			Capital Holdings			Other(a)			NextEra Energy Consoli- dated
	(millions)
Operating revenues	$	-		$	4,843		$	10,474		$	15,317		$	-		$	4,164		$	11,479		$	15,643		$	-		$	4,770		$	11,640		$	16,410
Operating expenses		(4	)		(3,446	)		(8,624	)		(12,074	)		-			(3,151	)		(9,898	)		(13,049	)		-			(3,474	)		(10,111	)		(13,585	)
Interest expense		(15	)		(618	)		(346	)		(979	)		(17	)		(531	)		(301	)		(849	)		(18	)		(479	)		(316	)		(813	)
Other income (deductions) - net		1,947			188			(1,910	)		225			1,632			160			(1,595	)		197			1,663			44			(1,630	)		77
Income (loss) before income taxes		1,928			967			(406	)		2,489			1,615			642			(315	)		1,942			1,645			861			(417	)		2,089
Income tax expense (benefit)		(29	)		(19	)		580			532			-			(145	)		472			327			6			2			442			450
Net income (loss)	$	1,957		$	986		$	(986	)	$	1,957		$	1,615		$	787		$	(787	)	$	1,615		$	1,639		$	859		$	(859	)	$	1,639

¾¾¾¾¾¾¾¾¾¾

(a)   Represents FPL and consolidating adjustments.

Condensed Consolidating Balance Sheets

	December 31, 2010											December 31, 2009
	NextEra Energy (Guaran- tor)		Capital Holdings			Other(a)			NextEra Energy Consoli- dated			NextEra Energy (Guaran- tor)		Capital Holdings			Other(a)			NextEra Energy Consoli- dated
	(millions)
PROPERTY, PLANT AND EQUIPMENT
Electric utility plant in service and other property	$	19	$	21,779		$	32,423		$	54,221		$	2	$	19,185		$	30,982		$	50,169
Less accumulated depreciation and amortization		-		(4,275	)		(10,871	)		(15,146	)		-		(3,513	)		(10,578	)		(14,091	)
Total property, plant and equipment - net		19		17,504			21,552			39,075			2		15,672			20,404			36,078
CURRENT ASSETS
Cash and cash equivalents		-		282			20			302			-		156			82			238
Receivables		654		1,380			548			2,582			453		1,247			547			2,247
Other		9		1,024			1,341			2,374			4		1,258			590			1,852
Total current assets		663		2,686			1,909			5,258			457		2,661			1,219			4,337
OTHER ASSETS
Investment in subsidiaries		14,150		-			(14,150	)		-			12,785		-			(12,785	)		-
Other		365		3,845			4,451			8,661			557		3,257			4,229			8,043
Total other assets		14,515		3,845			(9,699	)		8,661			13,342		3,257			(8,556	)		8,043
TOTAL ASSETS	$	15,197	$	24,035		$	13,762		$	52,994		$	13,801	$	21,590		$	13,067		$	48,458
CAPITALIZATION
Common shareholders' equity	$	14,461	$	4,359		$	(4,359	)	$	14,461		$	12,967	$	4,349		$	(4,349	)	$	12,967
Long-term debt		-		11,331			6,682			18,013			-		10,506			5,794			16,300
Total capitalization		14,461		15,690			2,323			32,474			12,967		14,855			1,445			29,267
CURRENT LIABILITIES
Debt due within one year		-		2,664			145			2,809			-		1,729			860			2,589
Accounts payable		-		571			553			1,124			-		453			539			992
Other		352		1,361			1,258			2,971			417		1,170			1,281			2,868
Total current liabilities		352		4,596			1,956			6,904			417		3,352			2,680			6,449
OTHER LIABILITIES AND DEFERRED CREDITS
Asset retirement obligations		-		556			1,083			1,639			-		585			1,833			2,418
Accumulated deferred income taxes		53		1,336			3,720			5,109			94		1,318			3,448			4,860
Regulatory liabilities		46		-			4,213			4,259			16		-			3,166			3,182
Other		285		1,857			467			2,609			307		1,480			495			2,282
Total other liabilities and deferred credits		384		3,749			9,483			13,616			417		3,383			8,942			12,742
COMMITMENTS AND CONTINGENCIES
TOTAL CAPITALIZATION AND LIABILITIES	$	15,197	$	24,035		$	13,762		$	52,994		$	13,801	$	21,590		$	13,067		$	48,458

¾¾¾¾¾¾¾¾¾¾

(a)   Represents FPL and consolidating adjustments.

108

Condensed Consolidating Statements of Cash Flows

	Year Ended December 31, 2010												Year Ended December 31, 2009												Year Ended December 31, 2008
	NextEra Energy (Guar- antor)			Capital Holdings			Other(a)			NextEra Energy Consoli- dated			NextEra Energy (Guar- antor)			Capital Holdings			Other(a)			NextEra Energy Consoli- dated			NextEra Energy (Guar- antor)			Capital Holdings			Other(a)			NextEra Energy Consoli- dated
	(millions)
NET CASH PROVIDED BY OPERATING ACTIVITIES	$	1,178		$	1,940		$	716		$	3,834		$	591		$	1,513		$	2,359		$	4,463		$	766		$	1,182		$	1,455		$	3,403
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures, independent power and other investments and nuclear fuel purchases		-			(3,140	)		(2,706	)		(5,846	)		-			(3,289	)		(2,717	)		(6,006	)		(12	)		(2,857	)		(2,367	)		(5,236	)
Capital contribution to FPL		(660	)		-			660			-			-			-			-			-			(75	)		-			75			-
Cash grants under the Recovery Act		-			428			160			588			-			100			-			100			-			-			-			-
Funding of loan		-			-			-			-			-			-			-			-			-			(500	)		-			(500	)
Other - net		-			5			(31	)		(26	)		(7	)		1			(23	)		(29	)		-			-			(72	)		(72	)
Net cash used in investing activities		(660	)		(2,707	)		(1,917	)		(5,284	)		(7	)		(3,188	)		(2,740	)		(5,935	)		(87	)		(3,357	)		(2,364	)		(5,808	)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt		-			2,800			924			3,724			-			2,704			516			3,220			-			3,238			589			3,827
Retirements of long-term debt		-			(727	)		(42	)		(769	)		-			(1,371	)		(264	)		(1,635	)		-			(1,118	)		(240	)		(1,358	)
Proceeds from sale of differential membership interests		-			261			-			261			-			-			-			-			-			-			-			-
Net change in short-term debt		-			(414	)		(716	)		(1,130	)		-			110			44			154			-			917			(69	)		848
Issuances of common stock - net		308			-			-			308			198			-			-			198			41			-			-			41
Dividends on common stock		(823	)		-			-			(823	)		(766	)		-			-			(766	)		(714	)		-			-			(714	)
Other - net		(3	)		(1,027	)		973			(57	)		(16	)		(26	)		46			4			(6	)		(675	)		687			6
Net cash provided by (used in) financing activities		(518	)		893			1,139			1,514			(584	)		1,417			342			1,175			(679	)		2,362			967			2,650
Net increase (decrease) in cash and cash equivalents		-			126			(62	)		64			-			(258	)		(39	)		(297	)		-			187			58			245
Cash and cash equivalents at beginning of year		-			156			82			238			-			414			121			535			-			227			63			290
Cash and cash equivalents at end of year	$	-		$	282		$	20		$	302		$	-		$	156		$	82		$	238		$	-		$	414		$	121		$	535

¾¾¾¾¾¾¾¾¾¾

(a)   Represents FPL and consolidating adjustments.

109

NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Concluded)

17.  Quarterly Data (Unaudited)

Condensed consolidated quarterly financial information is as follows:

	March 31(a)				June 30(a)				September 30(a)				December 31(a)
	(millions, except per share amounts)
NEXTERA ENERGY:
2010
Operating revenues(b)	$	3,622			$	3,591			$	4,691			$	3,413
Operating income(b)	$	939			$	709			$	1,125			$	469
Net income(b)	$	556			$	417			$	720			$	263
Earnings per share(c)	$	1.36			$	1.02			$	1.75			$	0.64
Earnings per share - assuming dilution(c)	$	1.36			$	1.01			$	1.74			$	0.63
Dividends per share	$	0.50			$	0.50			$	0.50			$	0.50
High-low common stock sales prices	$	53.75	-	45.29	$	53.50	-	47.96	$	55.98	-	48.44	$	56.26	-	50.00
2009
Operating revenues(b)	$	3,705			$	3,811			$	4,473			$	3,655
Operating income(b)	$	583			$	605			$	849			$	557
Net income(b)	$	364			$	370			$	533			$	349
Earnings per share(c)	$	0.90			$	0.92			$	1.32			$	0.86
Earnings per share - assuming dilution(c)	$	0.90			$	0.91			$	1.31			$	0.85
Dividends per share	$	0.4725			$	0.4725			$	0.4725			$	0.4725
High-low common stock sales prices	$	53.99	-	41.48	$	59.00	-	49.70	$	60.61	-	53.13	$	56.57	-	48.55
FPL:
2010
Operating revenues(b)	$	2,328			$	2,580			$	3,116			$	2,461
Operating income(b)	$	393			$	501			$	584			$	371
Net income(b)	$	191			$	265			$	308			$	181
2009
Operating revenues(b)	$	2,573			$	2,864			$	3,301			$	2,753
Operating income(b)	$	262			$	396			$	554			$	369
Net income(b)	$	127			$	213			$	306			$	186

¾¾¾¾¾¾¾¾¾¾

(a)	In the opinion of NextEra Energy and FPL, all adjustments, which consist of normal recurring accruals necessary to present a fair statement of the amounts shown for such periods, have been made.  Results of operations for an interim period generally will not give a true indication of results for the year.
(b)	The sum of the quarterly amounts may not equal the total for the year due to rounding.
(c)	The sum of the quarterly amounts may not equal the total for the year due to rounding and changes in weighted-average number of common shares outstanding.

110

Item 9.  Changes in and Disagreements With Accountants on Accounting and Financial Disclosure

None

Item 9A.  Controls and Procedures

Disclosure Controls and Procedures

As of December 31, 2010, each of NextEra Energy and FPL had performed an evaluation, under the supervision and with the participation of its management, including NextEra Energy'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 Rule 13a-15(e) or 15d-15(e)).  Based upon that evaluation, the chief executive officer and chief financial officer of each of NextEra Energy and FPL concluded that the company's disclosure controls and procedures were effective as of December 31, 2010.

Internal Control Over Financial Reporting

(a)	Management's Annual Report on Internal Control Over Financial Reporting See Item 8. Financial Statements and Supplementary Data.
(b)	Attestation Report of the Independent Registered Public Accounting Firm See Item 8. Financial Statements and Supplementary Data.
(c)	Changes in Internal Control Over Financial Reporting
	NextEra Energy 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 NextEra Energy and FPL.  However, there has been no change in NextEra Energy's or FPL's internal control over financial reporting that occurred during NextEra Energy's and FPL's most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, NextEra Energy's or FPL's internal control over financial reporting.

Item 9B.  Other Information

The following amounts previously reported in the condensed consolidated statements of cash flows and proceeds from sale of securities in Note 4 to the respective Quarterly Reports on Form 10-Q have been restated primarily to include purchase and sale activities related to overnight securities to be consistent with prior years' quarters.  Total cash flows from operating, investing and financing activities did not change as a result of these restatements.

	March 31, 2010		June 30, 2010		September 30, 2010
			(millions)
NEXTERA ENERGY:
Proceeds from sale of securities in special use funds:
As reported	$	1,900	$	3,063	$	4,092
As restated	$	2,563	$	4,138	$	5,350
Purchases of securities in special use funds:
As reported	$	1,937	$	3,123	$	4,177
As restated	$	2,600	$	4,198	$	5,435
FPL:
Proceeds from sale of securities in special use funds:
As reported	$	1,608	$	2,425	$	3,051
As restated	$	2,199	$	3,313	$	4,088
Purchases of securities in special use funds:
As reported	$	1,639	$	2,472	$	3,114
As restated	$	2,230	$	3,360	$	4,151

111

PART III

Item 10.  Directors, Executive Officers and Corporate Governance

The information required by this item will be included under the headings "Business of the Annual Meeting," "Corporate Governance and Board Matters" and "Information About NextEra Energy and Management" in NextEra Energy's Proxy Statement which will be filed with the SEC in connection with the 2011 Annual Meeting of Shareholders (NextEra Energy's Proxy Statement) and is incorporated herein by reference, or is included in Item 1. Business - Executive Officers of NextEra Energy.

NextEra Energy has adopted the NextEra Energy, Inc. Code of Ethics for Senior Executive and Financial Officers (the Senior Financial Executive Code), which is applicable to the chief executive officer, the chief financial officer, the chief accounting officer and other senior executive and financial officers.  The Senior Financial Executive Code is available in the Governance section of NextEra Energy’s internet website at www.nexteraenergy.com.  Any amendments to, or waivers of any provision of, the Senior Financial Executive Code which are required to be disclosed to shareholders under applicable SEC rules will be disclosed on the NextEra Energy website at the address listed above within the time period required under SEC rules from time to time.

Item 11.  Executive Compensation

The information required by this item will be included in NextEra Energy's Proxy Statement under the headings "Executive Compensation" and "Corporate Governance and Board Matters" and is incorporated herein by reference.

Item 12.  Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

The information required by this item will be included in NextEra Energy's Proxy Statement under the headings "Business of the Annual Meeting" and "Information About NextEra Energy and Management" and is incorporated herein by reference.

Item 13.  Certain Relationships and Related Transactions, and Director Independence

The information required by this item, to the extent applicable, will be included in NextEra Energy's Proxy Statement under the heading "Corporate Governance and Board Matters" and is incorporated herein by reference.

Item 14.  Principal Accounting Fees and Services

NextEra Energy - The information required by this item will be included in NextEra Energy's Proxy Statement under the heading "Audit-Related Matters" and is incorporated herein by reference.

FPL - The following table presents fees billed for professional services rendered by Deloitte & Touche LLP, the member firms of Deloitte Touche Tohmatsu, and their respective affiliates (collectively, Deloitte & Touche) for the fiscal years ended December 31, 2010 and 2009.  The amounts presented below reflect allocations from NextEra Energy for FPL's portion of the fees, as well as amounts billed directly to FPL.

	2010		2009
Audit fees(a)	$	2,724,000	$	2,706,000
Audit-related fees(b)		423,000		252,000
Tax fees(c)		33,000		30,000
All other fees(d)		197,000		4,000
Total	$	3,377,000	$	2,992,000

¾¾¾¾¾¾¾¾¾¾

(a)	Audit fees consist of fees billed for professional services rendered for the audit of FPL's and NextEra Energy's annual consolidated financial statements for the fiscal year, the reviews of the financial statements included in FPL's and NextEra Energy's Quarterly Reports on Form 10-Q for the fiscal year and the audit of the effectiveness of internal control over financial reporting, comfort letters, consents, and other services related to SEC matters, services in connection with annual and semi-annual filings of NextEra Energy's financial statements with the Japanese Ministry of Finance and accounting consultations to the extent necessary for Deloitte & Touche to fulfill its responsibility under Public Company Accounting Oversight Board standards.
(b)	Audit-related fees consist of fees billed for assurance and related services that are reasonably related to the performance of the audit or review of FPL's and NextEra Energy's consolidated financial statements and are not reported under audit fees.  These fees primarily related to audits of subsidiary financial statements, comfort letters, consents and other services related to subsidiary (non-SEC registrant) financing activities, consultation on accounting standards and on transactions, agreed-upon procedures and examinations related to applications for government grants.
(c)	Tax fees consist of fees billed for professional services rendered for tax compliance, tax advice and tax planning.  In 2010 and 2009, all tax fees paid related to tax compliance services.
(d)	All other fees consist of fees for products and services other than the services reported under the other named categories.  In 2010, these fees related to training, the review of the Smart Grid Grant process and the review of Enterprise Risk Management reporting.  In 2009, these fees related to the use of data extraction software.

112

In accordance with the requirements of Section 404 of the Sarbanes-Oxley Act of 2002, NextEra Energy's Audit Committee's pre-approval policy for services provided by the independent auditor to FPL and the charter of the Audit Committee, all services performed by Deloitte & Touche are approved in advance by the Audit Committee, except for audits of certain trust funds where the fees are paid by the trust.  Audit and audit-related services specifically identified in an appendix to the pre-approval policy are pre-approved by the Audit Committee each year.  This pre-approval allows management to request the specified audit and audit-related services on an as-needed basis during the year, provided any such services are reviewed with the Audit Committee at its next regularly scheduled meeting.  Any audit or audit-related service for which the fee is expected to exceed $250,000, or that involves a service not listed on the pre-approval list, must be specifically approved by the Audit Committee prior to commencement of such work.  In addition, the Audit Committee approves all services other than audit and audit-related services performed by Deloitte & Touche in advance of the commencement of such work.  The Audit Committee has delegated to the chairman of the committee the right to approve audit, audit-related, tax and other services, within certain limitations, between meetings of the Audit Committee, provided any such decision is presented to the Audit Committee at its next regularly scheduled meeting.  The Audit Committee reviews on a quarterly basis a schedule of all services for which Deloitte & Touche has been engaged and the estimated fees for those services.  In 2010 and 2009, no services provided to NextEra Energy or FPL by Deloitte & Touche were appro ved by the Audit Committee after services were rendered pursuant to Rule 2-01(c)(7)(i)(C) of Regulation S-X (which provides for a waiver of the otherwise applicable pre-approval requirement if certain conditions are met).

PART IV

Item 15.  Exhibits, Financial Statement Schedules

			Page(s)
(a)	1.	Financial Statements
		Management's Report on Internal Control Over Financial Reporting	58
		Attestation Report of Independent Registered Public Accounting Firm	59
		Report of Independent Registered Public Accounting Firm	60
		NextEra Energy:
		Consolidated Statements of Income	61
		Consolidated Balance Sheets	62
		Consolidated Statements of Cash Flows	63
		Consolidated Statements of Common Shareholders' Equity	64
		FPL:
		Consolidated Statements of Income	65
		Consolidated Balance Sheets	66
		Consolidated Statements of Cash Flows	67
		Consolidated Statements of Common Shareholder's Equity	68
		Notes to Consolidated Financial Statements	69 - 110
	2.	Financial Statement Schedules - Schedules are omitted as not applicable or not required.
	3.	Exhibits (including those incorporated by reference)
		Certain exhibits listed below refer to "FPL Group" and "FPL Group Capital," and were effective prior to the change of the name FPL Group, Inc. to NextEra Energy, Inc., and of the name FPL Group Capital Inc to NextEra Energy Capital Holdings, Inc., during 2010.

Exhibit Number	Description	NextEra Energy	FPL
*3(i)a	Restated Articles of Incorporation of NextEra Energy (filed as Exhibit 3(i) to Form 10-Q for the quarter ended June 30, 2010, File No. 1-8841)	x
3(i)b	Restated Articles of Incorporation of FPL		x
*3(ii)a	Amended and Restated Bylaws of NextEra Energy, as amended through May 21, 2010 (filed as Exhibit 3(ii) to Form 10-Q for the quarter ended June 30, 2010, File No. 1-8841)	x
*3(ii)b	Amended and Restated Bylaws of FPL, as amended through October 17, 2008 (filed as Exhibit 3(ii)b to Form 10-Q for the quarter ended September 30, 2008, File No. 2-27612)		x

113

Exhibit Number	Description	NextEra Energy	FPL
*4(a)	Mortgage and Deed of Trust dated as of January 1, 1944, and One hundred and sixteen Supplements thereto, between FPL and Deutsche Bank Trust Company Americas, Trustee (filed as Exhibit B-3, File No. 2-4845; Exhibit 7(a), File No. 2-7126; Exhibit 7(a), File No. 2-7523; Exhibit 7(a), File No. 2-7990; Exhibit 7(a), File No. 2-9217; Exhibit 4(a)-5, File No. 2-10093; Exhibit 4(c), File No. 2-11491; Exhibit 4(b)-1, File No. 2-12900; Exhibit 4(b)-1, File No. 2-13255; Exhibit 4(b)-1, File No. 2-13705; Exhibit 4(b)-1, File No. 2-13925; Exhibit 4(b)-1, File No. 2-15088; Exhibit 4(b)-1, File No. 2-15677; Exhibit 4(b)-1, File No. 2-20501; Exhibit 4(b)-1, File No. 2-22104; Exhibit 2(c), File No. 2-23142; Exhibit 2(c), File No. 2-24195; Exhibit 4(b)-1, File No. 2-25677; Exhibit 2(c), File No. 2-27612; Exhibit 2(c), File No. 2-29001; Exhibit 2(c), F ile No. 2-30542; Exhibit 2(c), File No. 2-33038; Exhibit 2(c), File No. 2-37679; Exhibit 2(c), File No. 2-39006; Exhibit 2(c), File No. 2-41312; Exhibit 2(c), File No. 2-44234; Exhibit 2(c), File No. 2-46502; Exhibit 2(c), File No. 2-48679; Exhibit 2(c), File No. 2-49726; Exhibit 2(c), File No. 2-50712; Exhibit 2(c), File No. 2-52826; Exhibit 2(c), File No. 2-53272; Exhibit 2(c), File No. 2-54242; Exhibit 2(c), File No. 2-56228; Exhibits 2(c) and 2(d), File No. 2-60413; Exhibits 2(c) and 2(d), File No. 2-65701; Exhibit 2(c), File No. 2-66524; Exhibit 2(c), File No. 2-67239; Exhibit 4(c), File No. 2-69716; Exhibit 4(c), File No. 2-70767; Exhibit 4(b), File No. 2-71542; Exhibit 4(b), File No. 2-73799; Exhibits 4(c), 4(d) and 4(e), File No. 2-75762; Exhibit 4(c), File No. 2-77629; Exhibit 4(c), File No. 2-79557; Exhibit 99(a) to Post-Effective Amendment No. 5 to Form S-8, File No. 33-18669; Exhibit 99(a) to Post-Effective Amendment No. 1 to Form S-3, File No. 33-46076; Ex hibit 4(b) to Form 10-K for the year ended December 31, 1993, File No. 1-3545; Exhibit 4(i) to Form 10-Q for the quarter ended June 30, 1994, File No. 1-3545; Exhibit 4(b) to Form 10-Q for the quarter ended June 30, 1995, File No. 1-3545; Exhibit 4(a) to Form 10-Q for the quarter ended March 31,1996, File No. 1-3545; Exhibit 4 to Form 10-Q for the quarter ended June 30, 1998, File No. 1-3545; Exhibit 4 to Form 10-Q for the quarter ended March 31, 1999, File No. 1-3545; Exhibit 4(f) to Form 10-K for the year ended December 31, 2000, File No. 1-3545; Exhibit 4(g) to Form 10-K for the year ended December 31, 2000, File No. 1-3545; Exhibit 4(o), File No. 333-102169; Exhibit 4(k) to Post-Effective Amendment No. 1 to Form S-3, File No. 333-102172; Exhibit 4(l) to Post-Effective Amendment No. 2 to Form S-3, File No. 333-102172; Exhibit 4(m) to Post-Effective Amendment No. 3 to Form S-3, File No. 333-102172; Exhibit 4(a) to Form 10-Q for the quarter ended September 30, 2004, File No. 2-27612; Exhibit 4(f) to Amendment No. 1 to Form S-3, File No. 333-125275; Exhibit 4(y) to Post-Effective Amendment No. 2 to Form S-3, File Nos. 333-116300, 333-116300-01 and 333-116300-02; Exhibit 4(z) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-116300, 333-116300-01 and 333-116300-02; Exhibit 4(b) to Form 10-Q for the quarter ended March 31, 2006, File No. 2-27612; Exhibit 4(a) to Form 8-K dated April 17, 2007, File No. 2-27612; Exhibit 4 to Form 8-K dated October 10, 2007, File No. 2-27612; Exhibit 4 to Form 8-K dated January 16, 2008, File No. 2-27612; Exhibit 4(a) to Form 8-K dated March 17, 2009, File No. 2-27612; Exhibit 4 to Form 8-K dated February 9, 2010, File No. 2-27612; and Exhibit 4 to Form 8-K dated December 9, 2010, File No. 2-27612)	x	x
*4(b)	Indenture, dated as of June 1, 1999, between FPL Group Capital and The Bank of New York Mellon, as Trustee (filed as Exhibit 4(a) to Form 8-K dated July 16, 1999, File No. 1-8841)	x
*4(c)	Guarantee Agreement between FPL Group (as Guarantor) and The Bank of New York Mellon (as Guarantee Trustee) dated as of June 1, 1999 (filed as Exhibit 4(b) to Form 8-K dated July 16, 1999, File No. 1-8841)	x
*4(d)	Officer's Certificate of FPL Group Capital, dated August 18, 2006, creating the 5 5/8% Debentures, Series due September 1, 2011 (filed as Exhibit 4 to Form 8-K dated August 18, 2006, File No. 1-8841)	x
*4(e)	Officer's Certificate of FPL Group Capital dated June 17, 2008, creating the 5.35% Debentures, Series due June 15, 2013 (filed as Exhibit 4(a) to Form 8-K dated June 17, 2008, File No. 1-8841)	x

114

Exhibit Number	Description	NextEra Energy	FPL
*4(f)	Officer's Certificate of FPL Group Capital dated June 17, 2008, creating the Floating Rate Debentures, Series due June 17, 2011 (filed as Exhibit 4(b) to Form 8-K dated June 17, 2008, File No. 1-8841)	x
*4(g)	Officer's Certificate of FPL Group Capital dated December 12, 2008, creating the 7 7/8% Debentures, Series due December 15, 2015 (filed as Exhibit 4 to Form 8-K dated December 12, 2008, File No. 1-8841)	x
*4(h)	Officer's Certificate of FPL Group Capital, dated March 9, 2009, creating the 6.00% Debentures, Series due March 1, 2019 (filed as Exhibit 4 to Form 8-K dated March 9, 2009, file No. 1-8841)	x
*4(i)	Officer's Certificate of FPL Group Capital, dated May 26, 2009, creating the Series C Debentures due June 1, 2014 (filed as Exhibit 4(c) to Form 8-K dated May 22, 2009, File No. 1-8841)	x
*4(j)	Officer's Certificate of FPL Group Capital dated November 10, 2009, creating the Floating Rate Debentures, Series due November 9, 2012 (filed as Exhibit 4 to Form 8-K dated November 10, 2009, File No. 1-8841)	x
*4(k)	Officer's Certificate of FPL Group Capital dated May 18, 2010, creating the Debentures, 2.55% Series due November 15, 2013 (filed as Exhibit 4 to Form 8-K dated May 18, 2010, File No. 1-8841)	x
*4(l)	Officer's Certificate of FPL Group Capital, dated August 31, 2010, creating the Debentures, 2.60% Series due September 1, 2015 (filed as Exhibit 4 to Form 8-K dated August 31, 2010, File No. 1-8841)	x
*4(m)	Officer's Certificate of FPL Group Capital, dated September 21, 2010, creating the Series D Debentures due September 1, 2015 (filed as Exhibit 4(c) to Form 8-K dated September 15, 2010, File No. 1-8841)	x
*4(n)	Indenture (For Unsecured Subordinated Debt Securities relating to Trust Securities) dated as of March 1, 2004 among FPL Group Capital, FPL Group (as Guarantor) and The Bank of New York Mellon (as Trustee) (filed as Exhibit 4(au) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-102173, 333-102173-01, 333-102173-02 and 333-102173-03)	x
*4(o)	Preferred Trust Securities Guarantee Agreement between FPL Group (as Guarantor) and The Bank of New York Mellon (as Guarantee Trustee) relating to FPL Group Capital Trust I, dated as of March 15, 2004 (filed as Exhibit 4(aw) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-102173, 333-102173-01, 333-102173-02 and 333-102173-03)	x
*4(p)	Amended and Restated Trust Agreement relating to FPL Group Capital Trust I, dated as of March 15, 2004 (filed as Exhibit 4(at) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-102173, 333-102173-01, 333-102173-02 and 333-102173-03)	x
*4(q)	Agreement as to Expenses and Liabilities of FPL Group Capital Trust I, dated as of March 15, 2004 (filed as Exhibit 4(ax) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-102173, 333-102173-01, 333-102173-02 and 333-102173-03)	x
*4(r)	Officer's Certificate of FPL Group Capital and FPL Group, dated March 15, 2004, creating the 5 7/8% Junior Subordinated Debentures, Series due March 15, 2044 (filed as Exhibit 4(av) to Post-Effective Amendment No. 3 to Form S-3, File Nos. 333-102173, 333-102173-01, 333-102173-02 and 333-102173-03)	x
*4(s)	Indenture (For Unsecured Subordinated Debt Securities) dated as of September 1, 2006, among FPL Group Capital, FPL Group (as Guarantor) and The Bank of New York Mellon (as Trustee) (filed as Exhibit 4(a) to Form 8-K dated September 19, 2006, File No. 1-8841)	x

115

Exhibit Number	Description	NextEra Energy	FPL
*4(t)	Officer's Certificate of FPL Group Capital and FPL Group dated September 19, 2006, creating the Series A Enhanced Junior Subordinated Debentures due 2066 (filed as Exhibit 4(b) to Form 8-K dated September 19, 2006, File No. 1-8841)	x
*4(u)	Officer's Certificate of FPL Group Capital and FPL Group dated September 19, 2006, creating the Series B Enhanced Junior Subordinated Debentures due 2066 (filed as Exhibit 4(c) to Form 8-K dated September 19, 2006, File No. 1-8841)	x
*4(v)	Replacement Capital Covenant dated September 19, 2006 by FPL Group Capital and FPL Group relating to FPL Group Capital's Series A and Series B Enhanced Junior Subordinated Debentures due 2066 (filed as Exhibit 4(d) to Form 8-K dated September 19, 2006, File No. 1-8841)	x
*4(w)	Officer's Certificate of FPL Group Capital and FPL Group dated June 12, 2007, creating the Series C Junior Subordinated Debentures due 2067 (filed as Exhibit 4(a) to Form 8-K dated June 12, 2007, File No. 1-8841)	x
*4(x)	Replacement Capital Covenant, dated June 12, 2007, by FPL Group Capital and FPL Group relating to FPL Group Capital's Series C Junior Subordinated Debentures due 2067 (filed as Exhibit 4(b) to Form 8-K dated June 12, 2007, File No. 1-8841)	x
*4(y)	Officer's Certificate of FPL Group Capital and FPL Group dated September 17, 2007, creating the Series D Junior Subordinated Debentures due 2067 (filed as Exhibit 4(a) to Form 8-K dated September 17, 2007, File No. 1-8841)	x
*4(z)	Officer's Certificate of FPL Group Capital and FPL Group dated September 18, 2007, creating the Series E Junior Subordinated Debentures due 2067 (filed as Exhibit 4(b) to Form 8-K dated September 17, 2007, File No. 1-8841)	x
*4(aa)	Replacement Capital Covenant, dated September 18, 2007, by FPL Group Capital and FPL Group relating to FPL Group Capital's Series D and Series E Junior Subordinated Debentures due 2067 (filed as Exhibit 4(c) to Form 8-K dated September 17, 2007, File No. 1-8841)	x
*4(bb)	Officer's Certificate of FPL Group Capital and FPL Group, dated March 19, 2009, creating the Series F Junior Subordinated Debentures due 2069 (filed as Exhibit 4(b) to Form 8-K dated March 17, 2009, File No. 1-8841)	x
*4(cc)	Replacement Capital Covenant, dated March 19, 2009, by FPL Group Capital and FPL Group (filed as Exhibit 4(c) to Form 8-K dated March 17, 2009, File No. 1-8841)	x
*4(dd)	Indenture (for Securing Senior Secured Bonds, Series A), dated May 22, 2007, between FPL Recovery Funding LLC (as Issuer) and The Bank of New York Mellon (as Trustee and Securities Intermediary) (filed as Exhibit 4.1 to Form 8-K dated May 22, 2007 and filed June 1, 2007, File No. 333-141357)		x
*4(ee)	Purchase Contract Agreement, dated as of May 1, 2009, between FPL Group and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(a) to Form 8-K dated May 22, 2009, File No. 1-8841)	x
*4(ff)	Pledge Agreement, dated as of May 1, 2009, among FPL Group, Deutsche Bank Trust Company Americas, as Collateral Agent, Custodial Agent and Securities Intermediary, and The Bank of New York Mellon, as Purchase Contract Agent and Trustee (filed as Exhibit 4(b) to Form 8-K dated May 22, 2009, File No. 1-8841)	x
*4(gg)	Purchase Contract Agreement, dated as of September 1, 2010, between NextEra Energy and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(a) to Form 8-K dated September 15, 2010, File No. 1-8841)	x

116

Exhibit Number	Description	NextEra Energy	FPL
*4(hh)	Pledge Agreement, dated as of September 1, 2010, among NextEra Energy, 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 15, 2010, File No. 1-8841)	x
*10(a)	FPL Group Supplemental Executive Retirement Plan, amended and restated effective April 1, 1997 (SERP) (filed as Exhibit 10(a) to Form 10-K for the year ended December 31, 1999, File No. 1-8841)	x	x
*10(b)	FPL Group Supplemental Executive Retirement Plan, amended and restated effective January 1, 2005 (Restated SERP) (filed as Exhibit 10(b) to Form 8-K dated December 12, 2008, File No. 1-8841)	x	x
*10(c)	Amendment Number 1 to the Restated SERP changing name to NextEra Energy, Inc. Supplemental Executive Retirement Plan (filed as Exhibit 10(b) to Form 10-Q for the quarter ended June 30, 2010, File No. 1-8841)	x	x
*10(d)	Appendix A1 (revised as of January 1, 2010) to the Restated SERP (filed as Exhibit 10(e) to form 10-K for the year ended December 31, 2009, File No. 1-8841)	x	x
*10(e)	Appendix A2 (revised as of August 16, 2010) to the Restated SERP (filed as Exhibit 10(a) to Form 10-Q for the quarter ended September 30, 2010, File No. 1-8841)	x	x
*10(f)	Amended and Restated Supplement to the Restated SERP as it applies to Lewis Hay, III effective January 1, 2005 (filed as Exhibit 10(c) to Form 8-K dated December 12, 2008, File No. 1-8841)	x	x
*10(g)	Supplement to the SERP as it applies to Lewis Hay, III effective March 22, 2002 (filed as Exhibit 10(g) to Form 10-K for the year ended December 31, 2001, File No. 1-8841)	x	x
*10(h)	Supplement to the Restated SERP relating to a special credit to certain executive officers and other officers effective February 15, 2008 (filed as Exhibit 10(g) to Form 10-K for the year ended December 31, 2007, File No. 1-8841)	x	x
*10(i)	Supplement to the Restated SERP effective February 15, 2008 as it applies to Armando Pimentel, Jr. (filed as Exhibit 10(i) to Form 10-K for the year ended December 31, 2007, File No. 1-8841)	x	x
*10(j)	Supplement to the SERP effective December 14, 2007 as it applies to Manoochehr K. Nazar (filed as Exhibit 10(j) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)	x	x
*10(k)	NextEra Energy (formerly known as FPL Group) Amended and Restated Long-Term Incentive Plan, most recently amended and restated on May 22, 2009 (filed as Exhibit 10(a) to Form 10-Q for the quarter ended June 30, 2009, File No. 1-8841)	x	x
*10(l)	FPL Group Long-Term Incentive Plan of 1985, as amended (filed as Exhibit 99(h) to Post-Effective Amendment No. 5 to Form S-8, File No. 33-18669)	x	x
*10(m)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Performance Share Award Agreement effective February 15, 2007 (filed as Exhibit 10(i) to Form 10-K for the year ended December 31, 2006, File No. 1-8841)	x	x
*10(n)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Performance Share Award Agreement effective February 15, 2008 (filed as Exhibit 10(c) to Form 8-K dated February 15, 2008, File No. 1-8841)	x	x

117

Exhibit Number	Description	NextEra Energy	FPL
*10(o)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Performance Share Award Agreement effective February 13, 2009 with Christopher A. Bennett, Paul I. Cutler, Chris N. Froggatt, Joseph T. Kelliher, Robert L. McGrath and Antonio Rodriguez (filed as Exhibit 10(l) to Form 10-K for the year ended December 31, 2008, File No. 1-8841)	x	x
*10(p)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Amended and Restated Performance Share Award Agreement effective December 10, 2009 with F. Mitchell Davidson, Lewis Hay, III, Manoochehr K. Nazar, Armando J. Olivera, Armando Pimentel, Jr., James L. Robo and Charles E. Sieving (filed as Exhibit 10(p) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)	x	x
*10(q)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Performance Share Award Agreement effective February 12, 2010 (filed as Exhibit 10(q) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)	x	x
*10(r)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Restricted Stock Award Agreement effective February 15, 2007 (filed as Exhibit 10(l) to Form 10-K for the year ended December 31, 2006, File No. 1-8841)	x	x
*10(s)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Restricted Stock Award Agreement effective February 15, 2008 (filed as Exhibit 10(a) to Form 8-K dated February 15, 2008, File No. 1-8841)	x	x
*10(t)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Restricted Stock Award Agreement effective February 13, 2009 (filed as Exhibit 10(q) to Form 10-K for the year ended December 31, 2008, File No. 1-8841)	x	x
*10(u)	Form of Amendment to Restricted Stock Award Agreements under the FPL Group Amended and Restated Long-Term Incentive Plan executed March 2009 between FPL Group and each of Christopher A. Bennett, F. Mitchell Davidson, Lewis Hay, III, Robert L. McGrath, Armando J. Olivera, Armando Pimentel, Jr., James L. Robo and Antonio Rodriguez (filed as Exhibit 10(c) to Form 10-Q for the quarter ended March 31, 2009, File No. 1-8841)	x	x
*10(v)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Restricted Stock Award Agreement effective February 12, 2010 (filed as Exhibit 10(w) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)	x	x
*10(w)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Stock Option Award - Non-Qualified Stock Option Agreement (filed as Exhibit 10(c) to Form 8-K dated December 29, 2004, File No. 1-8841)	x	x
*10(x)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Stock Option Award - Non-Qualified Stock Option Agreement (filed as Exhibit 10(d) to Form 8-K dated December 29, 2004, File No. 1-8841)	x	x
*10(y)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Stock Option Award - Non-Qualified Stock Option Agreement effective February 15, 2008 (filed as Exhibit 10(b) to Form 8-K dated February 15, 2008, File No. 1-8841)	x	x
*10(z)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Stock Option Award - Non-Qualified Stock Option Agreement effective February 13, 2009 (filed as Exhibit 10(u) to Form 10-K for the year ended December 31, 2008, File No. 1-8841)	x	x
*10(aa)	Form of FPL Group Amended and Restated Long-Term Incentive Plan - Non-Qualified Stock Option Agreement effective February 12, 2010 (filed as Exhibit 10(bb) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)	x	x

118

Exhibit Number	Description	NextEra Energy	FPL
*10(bb)	Form of FPL Group Amended and Restated Long-Term Incentive Plan Amended and Restated Deferred Stock Award Agreement effective February 12, 2010 between FPL Group and each of Moray P. Dewhurst and James L. Robo (filed as Exhibit 10(dd) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)	x	x
*10(cc)	FPL Group Executive Annual Incentive Plan as amended and restated on December 12, 2008 (filed as Exhibit 10(a) to Form 8-K dated December 12, 2008, File No. 1-8841)	x	x
10(dd)	NextEra Energy Deferred Compensation Plan effective January 1, 2005 as amended and restated through October 15, 2010	x	x
*10(ee)	FPL Group Deferred Compensation Plan, amended and restated effective January 1, 2003 (filed as Exhibit 10(k) to Form 10-K for the year ended December 31, 2002, File No. 1-8841)	x	x
*10(ff)	FPL Group Executive Long-Term Disability Plan effective January 1, 1995 (filed as Exhibit 10(g) to Form 10-K for the year ended December 31, 1995, File No. 1-8841)	x	x
*10(gg)	FPL Group Amended and Restated Non-Employee Directors Stock Plan, as amended and restated October 13, 2006 (filed as Exhibit 10(b) to Form 10-Q for the quarter ended September 30, 2006, File No. 1-8841)	x
*10(hh)	FPL Group 2007 Non-Employee Directors Stock Plan (filed as Exhibit 99 to Form S-8, File No. 333-143739)	x
*10(ii)	FPL Group Non-Employee Director Compensation Summary effective January 1, 2010 (filed as Exhibit 10(ll) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)	x
10(jj)	NextEra Energy Non-Employee Director Compensation Summary effective January 1, 2011	x
*10(kk)	Form of Amended and Restated Executive Retention Employment Agreement, as of December 12, 2008, between FPL Group and each of Christopher A. Bennett, Robert L. McGrath and Antonio Rodriguez (filed as Exhibit 10(g) to Form 8-K dated December 12, 2008, File No. 1-8841)	x	x
*10(ll)	Form of Amended and Restated Executive Retention Employment Agreement effective December 10, 2009 between FPL Group and each of Lewis Hay, III, Moray P. Dewhurst, James L. Robo, Armando J. Olivera, F. Mitchell Davidson, Armando Pimentel, Jr., and Charles E. Sieving (filed as Exhibit 10(nn) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)	x	x
*10(mm)	Amended and Restated Employment Letter with Lewis Hay, III dated December 10, 2009 (filed as Exhibit 10(pp) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)	x	x
*10(nn)	Executive Retention Employment Agreement between FPL Group and Joseph T. Kelliher dated as of May 21, 2009 (filed as Exhibit 10(b) to Form 10-Q for the quarter ended June 30, 2009, File No. 1-8841)	x	x
*10(oo)	Executive Retention Employment Agreement between FPL Group and Manoochehr K. Nazar dated as of January 1, 2010 (filed as Exhibit 10(rr) to Form 10-K for the year ended December 31, 2009, File No. 1-8841)	x	x
*10(pp)	Executive Retention Employment Agreement between NextEra Energy and Shaun J. Francis dated as of August 16, 2010 (filed as Exhibit 10(b) to Form 10-Q for the quarter ended September 30, 2010, File No. 1-8841)	x	x

119

Exhibit Number	Description	NextEra Energy	FPL
*10(qq)	Retention Agreement between FPL Group and Robert L. McGrath (filed as Exhibit 10(a) to Form 10-Q for the quarter ended June 30, 2010, File No. 1-8841)	x	x
*10(rr)	Guarantee Agreement between FPL Group and FPL Group Capital, dated as of October 14, 1998 (filed as Exhibit 10(y) to Form 10-K for the year ended December 31, 2001, File No. 1-8841)	x
12(a)	Computation of Ratios	x
12(b)	Computation of Ratios		x
21	Subsidiaries of NextEra Energy	x
23	Consent of Independent Registered Public Accounting Firm	x	x
31(a)	Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of NextEra Energy	x
31(b)	Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer of NextEra Energy	x
31(c)	Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of FPL		x
31(d)	Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer of FPL		x
32(a)	Section 1350 Certification of NextEra Energy	x
32(b)	Section 1350 Certification of FPL		x
101.INS	XBRL Instance Document	x
101.SCH	XBRL Schema Document	x
101.PRE	XBRL Presentation Linkbase Document	x
101.CAL	XBRL Calculation Linkbase Document	x
101.LAB	XBRL Label Linkbase Document	x
101.DEF	XBRL Definition Linkbase Document	x

¾¾¾¾¾¾¾¾¾¾

* Incorporated herein by reference

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

120

NEXTERA ENERGY, INC. SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

NextEra Energy, Inc.

JAMES L. ROBO

James L. Robo

President and Chief Operating Officer

Date:  February 25, 2011

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.

Signature and Title as of February 25, 2011:

LEWIS HAY, III	CHRIS N. FROGGATT
Lewis Hay, III Chairman and Chief Executive Officer and Director (Principal Executive Officer)	Chris N. Froggatt Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer)
ARMANDO PIMENTEL, JR.
Armando Pimentel, Jr. Executive Vice President, Finance and Chief Financial Officer (Principal Financial Officer)

Directors:

SHERRY S. BARRAT	TONI JENNINGS
Sherry S. Barrat	Toni Jennings
ROBERT M. BEALL, II	OLIVER D. KINGSLEY, JR.
Robert M. Beall, II	Oliver D. Kingsley, Jr.
J. HYATT BROWN	RUDY E. SCHUPP
J. Hyatt Brown	Rudy E. Schupp
JAMES L. CAMAREN	WILLIAM H. SWANSON
James L. Camaren	William H. Swanson
KENNETH B. DUNN	MICHAEL H. THAMAN
Kenneth B. Dunn	Michael H. Thaman
J. BRIAN FERGUSON	HANSEL E. TOOKES, II
J. Brian Ferguson	Hansel E. Tookes, II

121

FLORIDA POWER & LIGHT COMPANY SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized and in the capacities and on the date indicated.

Florida Power & Light Company

ARMANDO J. OLIVERA

Armando J. Olivera

President and Chief Executive Officer

and Director

(Principal Executive Officer)

Date:  February 25, 2011

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.

Signature and Title as of February 25, 2011:

ARMANDO PIMENTEL, JR.	KIMBERLY OUSDAHL
Armando Pimentel, Jr. Executive Vice President, Finance and Chief Financial Officer and Director (Principal Financial Officer)	Kimberly Ousdahl Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer)

Directors:

LEWIS HAY, III

Lewis Hay, III

JAMES L. ROBO

James L. Robo

ANTONIO RODRIGUEZ

Antonio Rodriguez

122

Supplemental Information to be Furnished With Reports Filed Pursuant to Section 15(d) of the Securities Exchange Act of 1934 by Registrants Which Have Not Registered Securities Pursuant to Section 12 of the Securities Exchange Act of 1934

No annual report, proxy statement, form of proxy or other proxy soliciting material has been sent to security holders of FPL during the period covered by this Annual Report on Form 10-K for the fiscal year ended December 31, 2010.

123

EX-3.(I)B

Exhibit 3(i)b

RESTATED ARTICLES OF INCORPORATION

OF

FLORIDA POWER & LIGHT COMPANY

1. The name of the corporation is FLORIDA POWER & LIGHT COMPANY.

2.  The Company is organized for the purpose of transacting any or all lawful business.

3.           (A)            AUTHORIZED CAPITAL.  After giving effect to the reduction in the number and classes of shares previously authorized, including, but not limited to, reductions in the number and classes of shares relating to the redemption, repurchase or other cancellation or retirement of the shares of 4 1/2% Preferred Stock of the par value of $100 each (hereinafter called "4 1/2% Preferred Stock") and the shares of 4 1/2% Preferred Stock Series A of the par value of $100 each (hereinafter called "Series A Stock"), the total number of shares which the corporation is authorized to issue, itemized by class and series, is as follows:

(1)           10,414,100 shares of Preferred Stock, par value $100 per share, without serial designation (hereinafter called “Preferred Stock”);

(2)           5,000,000 shares of Preferred Stock without par value (No Par Preferred Stock) without serial designation (hereinafter called “No Par Preferred Stock”);

(3)           5,000,000 shares of Subordinated Preferred Stock without par value (hereinafter called “Preference Stock”); and

(4)           1,000 shares of Common Stock without par value (hereinafter called “Common Stock.”).

(B)  PREFERRED STOCK, NO PAR PREFERRED STOCK AND COMMON STOCK.  Except as to variations provided for in paragraph (1) of this subsection (B), all shares of Preferred Stock and No Par Preferred Stock and each series thereof shall be alike and identical in every particular and all shares of Preferred Stock and No Par Preferred Stock and each series thereof shall be of equal rank and dignity with and have the distinguishing characteristics hereinafter described in this Section 3.  Each series of the Preferred Stock shall have distinguishing characteristics of the Series A Stock hereinafter described in this Section which shall be read as though the designation of such series of the Preferred Stock were substituted for “Series A Stock” wherever such term “Series A Stock” hereina fter appears in this Section 3 (but such designation shall not be so substituted in: (i) paragraph (4) (c) of subsection (B); (ii) paragraph (4) (d) of subsection (B); (iii) paragraph (5) of subsection (B); (iv) subsection (C); (v) subsection (D); (vi) subsection (E); and in each such case, except paragraph (5) of this subsection (B) and subsections (C), (D) and (E) the shares of the Preferred Stock and each series thereof shall, irrespective of whether or not any shares of the 4 1/2% Preferred Stock or of the Series A Stock are at the time outstanding, be deemed to be shares of stock ranking on a parity with the 4 1/2% Preferred Stock or of the Series A Stock as to dividends or distributions).  The shares of No Par Preferred Stock and each series thereof shall, irrespective of whether or not any shares of the 4 1/2% Preferred Stock or the Series A Stock are at the time outstanding, be deemed to be shares of stock ranking on a parity with the 4 1/2% Preferred Stock or the Series A Stock as to divid ends or distributions.  The distinguishing characteristics of each series of the Preferred Stock shall survive the redemption or other retirement of the Series A Stock.

(1)           The series of Preferred Stock and No Par Preferred Stock may vary in the following particulars:

(a)           the number of shares to constitute each such series and the distinctive designation thereof;

(b)           the annual rate or rates of dividends payable on shares of such series and the date from which such dividends shall commence to accrue;

(c)           the terms and conditions on which the shares of each such series may be redeemed or converted into another class of security and, subject to applicable provisions of the Articles of Incorporation, as amended, the manner of effecting such redemption;

(d)           the sinking funds provisions, if any, for the redemption or purchase of shares of each such series; and

(e)           with respect to the No Par Preferred Stock only, variations with respect to whole or fractional voting rights and involuntary liquidation values.

The different characteristics in (a), (b), (c), (d), and in (e) as to involuntary liquidation values, shall be stated and expressed in the resolution or resolutions providing for the issue of Preferred Stock or No Par Preferred Stock or any series thereof adopted by the Board of Directors or by the duly constituted Executive Committee or the duly constituted Stock Issuance Committee of the Company.  Whole or fractional voting rights of the No Par Preferred Stock shall be as provided under paragraph (3) of subsection (D) hereunder.

(2)           The Preferred Stock, and the No Par Preferred Stock, pari passu, each with the other, shall be entitled, but only when as declared by the Board of Directors, out of funds legally available for the payment of dividends, in preference to the Preference Stock and the Common Stock, to dividends at the rate per share of four and one-half per centum (4 1/2%) per annum of the par value thereof, and to dividends at the rate fixed by the Board of Directors or Executive Committee or Stock Issuance Committee pursuant to paragraph (1) of this subsection (B) for each series of the Preferred Stock and the No Par Preferred Stock, payable quarterly on December 1, March 1, June 1, and September 1 of each year to stockholders of record as of a date, not exceeding thirty (30) da ys and not less than ten (10) days preceding such dividend payment dates, to be fixed by the Board of Directors, such dividends to be cumulative from the dividend date immediately preceding the date of issue of the share to which such dividends shall pertain.  Dividends in full shall not be paid or set apart for payment on the Preferred Stock, or on the No Par Preferred Stock for any dividend period unless dividends in full have been or are contemporaneously paid or set apart for payment on all outstanding shares of the Preferred Stock and the No Par Preferred Stock for such dividend period and for all prior dividend periods.  When the stated dividends are not paid in full on the Preferred Stock, or on the No Par Preferred Stock the shares Preferred Stock and No Par Preferred Stock shall share ratably in the payment of dividends, including accumulations, if any, in accordance with the sums which would be payable on said shares if all dividends were paid in full.  A “divide nd period” is the period between any two consecutive dividend payment dates, including the first of such dates.

Dividends may be paid upon the Preference Stock or the Common Stock only when dividends have been paid or funds have been set apart for the payment of dividends as aforesaid on the Preferred Stock and the No Par Preferred Stock from the dates after which dividends thereon became cumulative to the end of the dividend period then current, and when all payments have been made or funds have been set aside for payments then or theretofore due under the terms of any sinking fund for the purchase or redemption of Preferred Stock and No Par Preferred Stock.

(3)           (a)           So long as any shares of Series A Stock are outstanding, the Company shall not, without the consent (given by a vote at a meeting called for that purpose) of at least two-thirds of the total number of shares of the Series A Stock then outstanding create or authorize any new stock ranking prior to the Series A Stock as to dividends, or in liquidation, dissolution, winding up or other distribution, or create or authorize any security convertible into shares of any such stock.

(b)           So long as any shares of Series A Stock are outstanding, the Company shall not without the consent (given by a vote at a meeting called for that purpose) of at least two-thirds of the total number of shares of the Series A Stock then outstanding amend, alter, change or repeal any of the express terms of the Series A Stock then outstanding in a manner substantially prejudicial to the holders thereof.

(c)           So long as any shares of the No Par Preferred Stock are outstanding, the Company shall not without the consent (given by a vote of the No Par Preferred Stock and all other preferred stocks ranking on a parity with the No Par Preferred Stock as to dividends or distributions, together as a class at a meeting called for that purpose) of the holders of at least two-thirds of the total number of votes attributable to the then outstanding No Par Preferred Stock and such other preferred stocks:

(i)           amend, alter or repeal any of the rights, preferences or powers of any series of the outstanding No Par Preferred Stock so as to alter materially any such rights, preferences or powers; or

(ii)           create or authorize any new stock ranking prior to the No Par Preferred Stock as to dividends or in liquidation, dissolution, winding up or other distribution or create or authorize any security convertible into shares of any such stock;

provided, however, that with respect to (i) above, preferred stocks other than the No Par Preferred Stock shall be entitled to vote as a member of said voting class only if the same right, preference or power of such preferred stocks are proposed to be materially amended, altered or repealed in substantially the same manner, and provided further that if any such amendment, alteration or repeal would alter materially the rights, preferences or powers of one or more, but not all, of the series of the No Par Preferred Stock or other preferred stocks ranking on a parity with the No Par Preferred Stock as to dividends or distributions, at the time outstanding, such consent shall be required only of the holders of at least two-thirds of the total number of votes attributable to the outstanding shares of all series so affected, voting as a class.  The consent required under this paragraph (3) (c) shall be in addition to such vote as may be required by Florida law.

(4)           So long as any shares of the No Par Preferred Stock are outstanding, the Company shall not without the consent (given by vote of the No Par Preferred Stock and all other preferred stocks ranking on a parity with the No Par Preferred Stock as to dividends or distributions, together as a class at a meeting called for that purpose) of the holders of a majority of the total number of votes attributable to the then outstanding No Par Preferred Stock and such other preferred stocks:

(a)           merge or consolidate with or into any other corporation or corporations or sell or otherwise dispose of all or substantially all of the assets of the Company, unless such merger or consolidation or sale or other disposition or the exchange, issuance or assumption of all securities to be issued or assumed in connection with any such merger or consolidation or sale or other disposition, shall have been ordered, approved or permitted by the regulatory authorities of the state or states or of the United States of America having jurisdiction with respect to such merger or consolidation or sale or other disposition or exchange, issuance or assumption of securities; provided that the provisions of this subparagraph (a) shall not apply to a purchase or other acquisiti on by the Company of franchises or assets of another corporation in any manner which does not involve a merger or consolidation; or

(b)           issue any unsecured notes, debentures or other securities representing unsecured indebtedness, or otherwise assume or incur any such unsecured indebtedness, for purposes other than (i) the refunding of any outstanding unsecured indebtedness theretofore issued or assumed by the Company, (ii) the reacquisition, redemption or other retirement of any indebtedness issued or assumed by the Company, or (iii) the reacquisition, redemption or other retirement of all outstanding shares of the Series A Stock and of all outstanding shares of any other class or series of stock ranking on a parity, as to dividends, or in liquidation, dissolution, winding up or other distribution, with the Series A Stock, if immediately after issuing, assuming or incurring such debt the tota l principal amount of all outstanding unsecured notes, debentures or other securities representing unsecured indebtedness of the Company, including unsecured indebtedness then to be issued, assumed or incurred would exceed 20% of the aggregate of (a) the total principal amount of all bonds or other securities representing secured indebtedness issued or assumed by the Company and then to be outstanding, and (b) the capital and surplus of the Company as then to be stated on the books of account of the Company; or

(c)           issue, sell, or otherwise dispose of any shares of any class of stock ranking prior to, or on parity with, the 4 1/2% Preferred Stock or the Series A Stock as to dividends, or in liquidation, dissolution, winding up or other distribution, unless the net income of the Company determined, after provision for depreciation and all taxes and in accordance with generally accepted accounting practices, to be available for the payment of dividends for a period of twelve (12) consecutive calendar months within the fifteen (15) calendar months immediately preceding the issuance, sale or disposition of such stock, is at least equal to twice the annual dividend requirements on all outstanding shares of the 4 1/2% Preferred Stock and of the Series A Stock and of all other classes of stock ranking prior to, or on a parity with, the 4 1/2% Preferred Stock or the Series A Stock as to dividends or distributions, including the shares proposed to be issued, and unless the gross income of the Company for such period, determined in accordance with generally accepted accounting practices (but in any event after deducting the amount for said period charged by the Company on its books to depreciation expense and all taxes) to be available for the payment of interest, shall have been at least one and one-half times the sum of (i) the annual interest charges on all interest bearing indebtedness of the Company and (ii) the annual dividend requirements on all outstanding shares of the 4 1/2% Preferred Stock and of the Series A Stock and of all other classes of stock ranking prior to or on a parity with, the 4 1/2% Preferred Stock or the Series A Stock as to dividends or distributions, including the shares proposed to be issued; provided, that there shall be excluded from the foregoing compu tation interest charges on all indebtedness and dividends on all shares of stock which are to be retired in connection with the issue of such additional shares; and provided, further, that in any case where such additional shares are to be issued in connection with the acquisition of new property, the gross income and the net income of the property to be so acquired may be included on a pro forma basis in the foregoing computation, computed on the same basis as the gross income and the net income of the Company; or

(d)           issue, sell, or otherwise dispose of any shares of any class of stock ranking prior to, or on a parity with the 4 1/2% Preferred Stock or the Series A Stock as to dividends or distributions, unless the aggregate of the capital of the Company applicable to the Common Stock and the surplus of the Company shall not be less than the aggregate amount payable on the involuntary liquidation, dissolution, or winding up of the Company, in respect of all shares of the 4 1/2% Preferred Stock and of the Series A Stock and all shares of stock, if any, ranking prior thereto, or on a parity therewith, as to dividends or distributions, which will be outstanding after the issue of the shares proposed to be issued; provided, that if, for the purposes of meeting the requirements of this subparagraph (d), it becomes necessary to take into consideration any earned surplus of the Company, the Company shall not thereafter pay any dividends on shares of Common Stock which would result in reducing the Company’s Common Stock Equity (the words “Common Stock Equity” meaning the sum of the stated value of the outstanding Common Stock and the earned surplus and the capital and paid-in surplus of the Company, whether or not available for the payment of dividends on the Common Stock) to an amount less than the aggregate amount payable, on involuntary liquidation, dissolution, or winding up of the Company, on all shares of the 4 1/2% Preferred Stock, of the Series A Stock and of any stock ranking prior to, or on a parity with, the 4 1/2% Preferred Stock or the Series A Stock as to dividends or distributions, at the time outstanding.

(5)           In the event of any voluntary liquidation, dissolution or winding up of the Company, the 4 1/2% Preferred Stock, the Series A Stock, the Preferred Stock and the No Par Preferred Stock, pari passu, with each with the other, shall have a preference over the Preference Stock and the Common Stock until an amount equal to the then current redemption price of all shares of the 4 1/2% Preferred Stock, the Series A Stock, the Preferred Stock and the No Par Preferred Stock shall have been paid.  In the event of any involuntary liquidation, dissolution or winding up of the Company, which shall include any such liquidation, dissolution or winding up which may arise out of or result from the condemnation or purchase of all or a major portion of the properties of the Company by (i) the United States Government or any authority, agency or instrumentality thereof, (ii) a state of the United States or any authority, agency or instrumentality thereof, or (iii) a district, cooperative or other association or entity not organized for profit, the 4 1/2% Preferred Stock, the Series A Stock, the Preferred Stock and the No Par Preferred Stock, pari passu, each with the other, shall also have a preference over the Preference Stock and the Common Stock until:  the full par value of all shares of the 4 1/2% Preferred Stock, the Series A Stock, and of the Preferred Stock, the involuntary liquidation value established by the Board of Directors or Executive Committee or Stock Issuance Committee pursuant to paragraph (1) of this subsection (B) with respect to the No Par Preferred Stock and, in each case, an amount equal to all accumulated and unpaid dividends thereon shall have been paid by dividends or distribution.  If the assets distributable on any liquidatio n, dissolution or winding up of the Company, whether voluntary or involuntary, shall be insufficient to permit the payment to the holders of the 4 1/2% Preferred Stock, the Series A Stock, the Preferred Stock and the No Par Preferred Stock of the full amounts to which they respectively are entitled as aforesaid, then said assets shall be distributed ratably among the holders of the 4 1/2% Preferred Stock, the Series A Stock, the Preferred Stock and the No Par Preferred Stock in proportion to the sums which would be payable on such liquidation, dissolution or winding up if all such sums were paid in full.

(6)           Notice of the intention of the Company to redeem all or any part of the  Preferred Stock or the No Par Preferred Stock shall be mailed not less than thirty days nor more than sixty days before the date of redemption to each holder of record of the Preferred Stock or No Par Preferred Stock to be redeemed, at his post office address as shown by the Company’s records and not less than thirty days nor more than sixty days notice of such redemption may be published in such manner as may be prescribed by resolution of the Board of Directors of the Company; and, in the event of such publication, no defect in the notice so mailed or in the mailing thereof shall affect the validity of the proceedings for the redemption of any shares so to be redeemed.&# 160; Contemporaneously with the mailing or the publication of such notice as aforesaid or at any time thereafter prior to the date of redemption, the Company may deposit the aggregate redemption price (or the portion thereof not already paid) with any bank or trust company in the City of New York, New York, or in the City of Miami, Florida, or, in the case of the Preferred Stock and the No Par Preferred Stock, any bank or trust company located anywhere in the United States of America and acting as registrar or transfer agent with respect to such stock, named in such notice, payable to the order of the record holders of the shares so to be redeemed, on the endorsement and surrender of their certificates, and thereupon said holders shall cease to be stockholders with respect to such shares; and from and after the making of such deposit such holders shall have no interest in or claim against the Company with respect to said shares, but shall be entitled only to receive such moneys from said bank or trust c ompany, with interest, if any, allowed by such bank or trust company on such moneys deposited as in this paragraph provided, on endorsement and surrender of their certificates, as aforesaid.  Any moneys so deposited, plus interest thereon, if any, remaining unclaimed at the end of six years from the date fixed for redemption, if thereafter requested by resolution of the Board of Directors, shall be repaid to the Company, and in the event of such repayment to the Company, such holders of record of the shares so redeemed as shall not have made claim against such moneys prior to such repayment to the Company shall be deemed to be unsecured creditors of the Company for an amount, without interest, equivalent to the amount deposited, plus interest thereon, if any, allowed by such bank or trust company, as above stated, for the redemption of such shares and so paid to the Company. Shares of the Preferred Stock or the No Par Preferred Stock which have been redeemed shall not be reissued.  If les s than all of the shares of any series of the Preferred Stock or the No Par Preferred Stock are to be redeemed, the shares to be redeemed shall be selected by lot or pro rata, in such manner as the Board of Directors of the Company shall determine, by an independent bank or trust company selected for that purpose by the Board of Directors of the Company.  Nothing in this paragraph contained shall limit any right of the Company to purchase or otherwise acquire any shares of the Preferred Stock or No Par Preferred Stock.

(7)           For the purpose of this paragraph (7): (a) the term “Common Stock Equity” shall mean the sum of the stated value of the outstanding Common Stock and the earned surplus and the capital and paid-in surplus of the Company, whether or not available for the payment of dividends on the Common Stock; (b) the term “total capitalization” shall mean the sum of the stated capital applicable to the outstanding stock of all classes of the Company, the earned surplus and the capital and paid-in surplus of the Company, whether or not available for the payment of dividends on the Common Stock of the Company, any premium on capital stock of the Company and the principal amount of all outstanding debt of the Company maturing more than twelve months after the date of the determination of the total capitalization; and (c) the term “dividends on Common Stock” shall embrace dividends on Common Stock (other than dividends payable only in shares of Common Stock), distributions on, and purchases or other acquisitions for value of, any Common Stock of the Company or other stock, if any, subordinate to the Series A Stock and the No Par Preferred Stock.  Subject to the rights of the holders of the Series A Stock, the No Par Preferred Stock and the Preference Stock and subordinate thereto (and subject and subordinate to the rights of any class of stock hereafter authorized), the Common Stock alone shall receive all dividends and shares in liquidation, dissolution, winding up or other distribution.  So long as any shares of the Series A Stock or the No Par Preferred Stock are outstanding, the Company shall not declare or pay any dividends on the Common Stock, except as follows:

(a)           If and so long as the Common Stock Equity at the end of the calendar month immediately preceding the date on which a dividend on Common Stock is declared is, or as a result of such dividend would become, less than 20% of total capitalization, the Company shall not declare such dividends in an amount which, together with all other dividends on Common Stock declared within the year ending with and including the date of such dividend declaration, exceeds 50% of the net income of the Company available for dividends on the Common Stock for the twelve full calendar months immediately preceding the month in which such dividends are declared; and

(b)           If and so long as the Common Stock Equity at the end of the calendar month immediately preceding the date on which a dividend on Common Stock is declared is, or as a result of such dividend would become, less than 25% but not less than 20% of total capitalization, the Company shall not declare dividends on the Common Stock in an amount which, together with all other dividends on Common Stock declared within the year ending with and including the date of such dividend declaration, exceeds 75% of the net income of the Company available for dividends on the Common Stock for the twelve full calendar months immediately preceding the month in which such dividends are declared; and

(c)           At any time when the Common Stock Equity is 25% or more of total capitalization, the Company may not declare dividends on shares of the Common Stock which would reduce the Common Stock Equity below 25% of total capitalization, except to the extent provided in subparagraphs (a) and (b) above.

(C)           PREFERENCE STOCK.  The Board of Directors or Executive Committee or Stock Issuance Committee is hereby expressly authorized, at any time or from time to time, to divide any or all of the shares of Preference Stock into series, and, before issuance, in the resolution or resolutions providing for the issue of shares of a particular series, to fix and determine the designations, preferences, qualifications, privileges, limitations, restrictions, options, conversion rights, and other special or relative rights in respect of the Preference Stock as a class, or of the particular series so established (except as otherwise expressly provided herein for all series) or both, to the fullest extent now or hereafter permitted by the laws of the State of Florida, including the rights of the Preference Stock as a class and the variations between different series in the following respects:

(1)           the number of shares to constitute each such series and the distinctive designation thereof;

(2)           the dividend terms, and the dates from which dividends shall commence to accrue;

(3)           the redemption price or prices for shares and the terms and conditions on which such shares may be redeemed;

(4)           the sinking fund provisions, if any, for the redemption or purchase of shares;

(5)           the preferential amount or amounts payable on shares in the event of the voluntary or involuntary liquidation of the Company;

(6)           the voting rights, if any, for the election of directors and for all other purposes;

(7)           the terms and conditions, if any, upon which shares may be converted and the class or classes or series of shares of the Company into which such shares may be converted; and

(8)           such other terms, limitations and relative rights and preferences, if any, of shares of Preference Stock as a class and of any such series of Preference Stock as the Board of Directors or Executive Committee or Stock Issuance Committee may, at the time of such resolution, lawfully fix and determine under the laws of the State of Florida.

The Preference Stock shall constitute a class of stock subordinate to the Series A Stock, Preferred Stock, and No Par Preferred Stock, as to dividends and in distribution.  So long as any shares of Series A Stock, Preferred Stock, or No Par Preferred Stock shall be outstanding, the preferences, privileges, rights and powers granted to or imposed upon the Preference Stock or any series thereof shall have no effect whatever on the preferences, privileges, rights and powers of the Series A Stock, Preferred Stock, and No Par Preferred Stock which shall retain the rights and shall be and remain prior in all respects to the Preference Stock.  All shares of Preference Stock shall be of equal rank with each other, regardless of series, and shall be identical with each other in all respects except as provided pursuan t to the first sentence of this subsection (C).

(1)           Dividends.  Out of the funds of the Company legally available for dividends, the holders of each series of the Preference Stock at the time outstanding shall be entitled to receive, if and when declared payable by the Board of Directors, such dividend as may be provided for that particular series by the Board of Directors or Executive Committee or Stock Issuance Committee pursuant to the first sentence of this subsection (C).  Dividends may be paid upon the Common Stock only when dividends have been paid or funds have been set apart for the payment of dividends on the Preference Stock, and when all payments have been made or funds have been set aside for payments then or theretofore due under the terms of any sinking fund for the purpose of redemption or purchase of Preference Stock.

(2)           Preference of the Preference Stock on Liquidation, etc.  In the event of any liquidation, dissolution or winding up of the Company, the holders of each series of the Preference Stock shall be entitled to receive an amount for each share hereof, equivalent to the fixed liquidation price for such series plus, in case such liquidation, dissolution or winding up shall have been voluntary, the fixed liquidation premium, if any, for such series, together in all cases with an amount equal to all dividends accrued or in arrears thereon to the date fixed for such payment, before any distribution of assets shall be made to the holders of the Common Stock or any other class of stock subordinate to the Preference Stock as to dividends or in distribution; but the holders of the Preference Stock shall be entitled to no further participation in such distribution, unless otherwise provided by the Board of Directors or Executive Committee or Stock Issuance Committee in the resolution or resolutions providing for the issuance of shares of a particular series.  If upon any such liquidation, dissolution or winding up, whether voluntary or involuntary, the assets distributable among the holders of the Preference Stock shall be insufficient to permit the payment of the full preferential amounts aforesaid, then such assets shall be distributed among the holders of all series of the Preference Stock then outstanding, ratably per share in proportion to the full preferential amounts per share to which they are respectively entitled as hereinbefore provided.  A consolidation or merger of the Company, a sale or transfer of all or substantially all of its assets as an entirety, or any purchase or redemption of stock of the Company of any class, shall not be rega rded as a “liquidation, dissolution or winding up” of the Company within the meaning of this paragraph (2).

(3)           Redemption, Repurchase and Retirement of the Preference Stock.  The Company, at its option, expressed by vote of its Board of Directors or Executive Committee or  Stock Issuance Committee, may at any time or from time to time redeem the whole or any part of the Preference Stock or of any series thereof at the applicable redemption price, as established by the Board of Directors or Executive Committee or Stock Issuance Committee, for each such series to be redeemed.

Notice of any proposed redemption of any shares of Preference Stock, the manner in which the same shall be carried out, and the rights and obligations of the Company and the holders of record of the shares of Preference Stock to be redeemed shall be as provided in paragraph (6) of subsection (B) hereof, which paragraph shall be read as though the designation of Preference Stock were substituted for No Par Preferred Stock wherever such term No Par Preferred Stock appears in paragraph (6) of subsection (B).

(D)           Subject to the provisions of subsection (E) of this Section 3:

(1)           The Common Stock shall have power to vote, and each holder of such Common Stock shall be entitled to one vote, in person or by proxy, for each share of such stock standing in his name on the books of the Company.

(2)           Except as expressly provided in this Section 3, the Series A Stock, the Preferred Stock and the No Par Preferred Stock shall have no power to vote.

(3)           When so entitled, the holders of No Par Preferred Stock shall have one vote for every $100 liquidation value established by the Board of Directors or the Executive Committee or the Stock Issuance Committee, provided that amounts less than $100 shall be afforded their proportional fractional vote.

(4)           The Preference Stock shall be entitled to such voting rights, if any, as may be provided in the resolution or resolutions of the Board of Directors or Executive Committee or Stock Issuance Committee.

(E)           Notwithstanding the provisions of paragraphs (1) and (2) of subsection (D) of this Section 3 and subject to any rights of the holders of the Preference Stock:

(1)           If and when dividends payable on any of the Preferred Stock (which, for the purposes of this subsection (E), shall be deemed to be the Series A Stock, and such other preferred stock, ranking on a parity with the Series A Stock as to dividends and distributions, as may be lawfully issued) shall be in default in an amount equal to four full quarterly payments or more per share, and thereafter until all dividends on any of the Preferred Stock in default shall have been paid, the holders of all of the then outstanding Preferred Stock, voting as a class (with voting rights of the No Par Preferred Stock determined in accordance with paragraph (3) of subsection (D), in contradistinction to the Common Stock as a class, shall be entitled to elect the smallest number of directors necessary to constitute a majority of the full Board of Directors, and the holders of Common Stock, voting separately as a class, shall be entitled to elect the remaining directors of the Company, anything in these Articles of Incorporation, as amended, to the contrary notwithstanding.  The terms of office, as directors, of all persons who may be directors of the Company at the time, shall terminate upon the election of a majority of the Board of Directors by the holders of the Preferred Stock, except that if the holders of the Common Stock shall not have elected the remaining directors of the Company, then, and only in that event, the directors of the Company in office just prior to the election of a majority of the Board of Directors by the holders of the Preferred Stock shall elect the remaining directors of the Company.  Thereafter, while such default continues and a majority of the Board is being elected by the holders of the Preferred Stock, the remaining directors, wheth er elected by directors, as aforesaid, or whether originally or later elected by holders of the Common Stock, shall continue in office until their successors are elected by holders of the Common Stock and shall qualify.  The term of office of the directors so elected by the holders of the Preferred Stock, voting as a class, and of the directors elected by the holders of the Common Stock, voting separately as a class shall be until the next annual meeting or until the privilege of the preferred stockholders to elect directors shall terminate as hereinafter provided, whichever shall be the earlier date, and until their successors shall have been elected and shall have qualified.

(2)           If and when all dividends then in default on any of the Preferred Stock then outstanding shall be paid (such dividends to be declared and paid out of any funds legally available therefor as soon as reasonably practicable), the holders of the Preferred Stock shall be divested of any privilege with respect to the election of directors which is conferred upon the holders of such Preferred Stock under this subsection (E) and the voting power of the holders of the Preferred Stock and the holders of the Common Stock shall revert to the status existing before the first dividend payment date on which dividends on any of the Preferred Stock were not paid in full, but always subject to the same provisions for vesting such privilege in the holders of the Preferred Stock in case of further like default or defaults in the payment of dividends thereon.  Upon termination of any such voting privilege upon payment of all accumulated and defaulted dividends on the Preferred Stock, the terms of office of all persons who have been elected directors of the Company by vote of the holders of the Preferred Stock as a class, pursuant to such voting privilege, shall forthwith terminate, and the resulting vacancies shall be filled by the vote of a majority of the remaining directors.

(3)           In case of any vacancy in the office of a director occurring among the directors elected by the holders of the Preferred Stock, voting as a class, the remaining directors elected by the holders of the Preferred Stock, by affirmative vote of a majority thereof, or the remaining director so elected if there be but one, may elect a successor or successors to hold office for the unexpired term or terms of the director or directors whose place or places shall be vacant.  In case of any vacancy in the office of a director occurring among the directors elected by the holders of the Common Stock, voting separately as a class, the remaining directors elected by the holders of the Common Stock, by affirmative vote of a majority thereof, or the remaining direct or so elected if there be but one, may elect a successor or successors to hold office for the unexpired term or terms of the director or directors whose place or places shall be vacant.

(4)           Whenever dividends on Preferred Stock shall be in default as provided in paragraph (1) of this subsection (E), it shall be the duty of the President, a Vice President or the Secretary of the Company, forthwith to cause notice to be given to the holders of the outstanding Preferred Stock and to the holders of the Common Stock of a meeting to be held at such time as the Company’s officers may fix, not less than ten (10) nor more than sixty (60) days after the accrual of such privilege, for the purpose of electing directors.  Each holder of record of any of the Preferred Stock, or his legal representative, shall be entitled at such meeting to one vote for each share of Preferred Stock standing in his name on the books of the Company, or, in the ca se of the No Par Preferred Stock, such vote as is determined in accordance with paragraph (3) of subsection (D).  At all meetings of stockholders held for the purpose of electing directors during such time as the holders of the Preferred Stock shall have the special right, voting separately as a class, to elect directors, the presence in person or by proxy of the holders of a majority of the outstanding Common Stock shall be required to constitute a quorum of such class for the election of directors, and the presence in person or by proxy of the holders of a majority of the outstanding Preferred Stock, including, in the case of the No Par Preferred Stock, a majority of the votes attributable to the outstanding No Par Preferred Stock, considered together as a class shall be required to constitute a quorum of such class for the election of directors; provided, however, that the absence of a quorum of the holders of either such Preferred Stock or Common Stock shall not prevent the election at any such meeting or adjournment thereof of directors by such other class, if the necessary quorum of the holders of stock of such other class is present in person or by proxy at such meeting or any adjournment thereof; and provided, further, that in the event a quorum of the holders of the Common Stock is present but a quorum of the holders of the Preferred Stock is not present, then the election of the directors elected by holders of the Common Stock shall not become effective and directors so elected by the holders of Common Stock shall not assume their offices and duties until the holders of the Preferred Stock, with a quorum present, shall have elected the directors they shall be entitled to elect; and provided, further, that in the absence of a quorum of holders of stock of either class, a majority of the holders of the stock of the class which lacks a quorum who are present in person or by proxy shall have power to adjourn the election of the directors to be elected by such class from time to time without noti ce other than announcement at the meeting, until the requisite quorum of holders of such class shall be present in person or by proxy, but such adjournment shall not be made to a date beyond the date for the mailing of the notice of the next annual meeting of the Company or special meeting in lieu thereof.

(5)           Voting privileges similar to those set forth in the preceding paragraphs (1), (2), (3) and (4) may be conferred upon any preferred stock hereafter authorized and, in that case, such preferred stock hereafter authorized shall have voting privileges equal to and concurrent with the voting privileges so set forth of the Series A Stock, and shall be deemed to be Preferred Stock for the purposes of this subsection (E).

4.  The stockholders of the Company shall have no pre-emptive rights.

5.  The corporation is to have perpetual existence.

6.  The registered office of the corporation is at 9250 West Flagler Street, Miami, Florida 33174 and the name of the registered agent at such address is J.E. Leon.

7.  The number of directors of the corporation shall be as set forth in the by-laws.

8.  For the regulation of the business and for the conduct of the affairs of the corporation, and to create, divide, limit and regulate the powers of the corporation, the Directors and each class of stockholders, provision is made as follows:

(a)            No stockholder shall have any right to inspect any account, book or document of the corporation, except as conferred by statute or authorized by the Directors.

(b)           Any Director may be removed by the Board of Directors and the resulting vacancy shall be filled until the next Annual Meeting of Stockholders by the Directors remaining in office.

(c)           In limitation of the application of Section 25 of the Act of the Legislature of the State of Florida hereinbefore mentioned, it is hereby provided that said Section 25 shall not apply to the corporation; and it is further provided that the unanimous vote of all stockholders of the corporation shall be required for any amendment of this agreement of consolidation which would eliminate the provisions of this subdivision (c) or in any way alter or modify the same.

(d)           The stockholders may alter or amend the by-laws of the corporation by a majority vote of all the outstanding stock of the corporation entitled to vote given at any meeting duly held as provided in the by-laws, the notice of which includes notice of the proposed alteration or amendment.  The Board of Directors may also alter or amend the by-laws at any time by affirmative vote of a majority of the Board of Directors given at a duly convened meeting of the Board of Directors, the notice of which includes notice of the proposed alteration or amendment, subject to the power of stockholders to change or repeal such by-laws.

EX-10.JJ

Exhibit 10(jj)

NEXTERA ENERGY, INC.

NON-EMPLOYEE DIRECTOR COMPENSATION SUMMARY

(Effective January 1, 2011)

Annual Retainer      (payable quarterly in common stock or cash)	$50,000
Board or Committee meeting fee	$2,000/meeting
Audit Committee Chair retainer (annual)      (payable quarterly)	$15,000
Other Committee Chair retainer (annual)      (payable quarterly)	$10,000
Annual grant of restricted stock      (under 2007 Non-Employee Directors Stock Plan)	that number of shares determined by dividing $110,000 by closing price of NextEra Energy common stock on effective date of grant (rounded up to the nearest 10 shares)
Miscellaneous	- Travel and Accident Insurance (including spouse coverage)
	- Certain directors accrue dividends and interest on the phantom stock units granted to them upon the termination of the Non-Employee Director Retirement Plan in 1996
	- Travel and related expenses while on Board business, and actual administrative or similar expenses incurred for Board or Committee business, are paid or reimbursed by the Company  Directors may travel on Company aircraft in accordance with the Company’s Aviation Policy (primarily to or from Board meetings and while on Board business; in limited circumstances for other reasonsif the Company would incur little if any incremental cost, space is available and the aircraft is already in use for another authorized purpose - may be accompanied by immediate family members when space is available).
	- Directors may participate in the Company’s Deferred Compensation Plan.
	- Directors may participate in the Company’s matching gift program, which matches gifts to educational institutions to a maximum of $10,000 per donor.

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)

	Years Ended December 31,
	2010		2009		2008		2007		2006
	(millions of dollars)
Earnings, as defined:
Net income	$	1,957	$	1,615	$	1,639	$	1,312	$	1,281
Income taxes		532		327		450		368		397
Fixed charges included in the determination of net income, as below		1,025		899		859		799		732
Amortization of capitalized interest		21		17		15		12		11
Distributed income of equity method investees		74		69		124		175		104
Less:  Equity in earnings of equity method investees		58		52		93		68		181
Total earnings, as defined	$	3,551	$	2,875	$	2,994	$	2,598	$	2,344
Fixed charges, as defined:
Interest expense	$	979	$	849	$	813	$	762	$	706
Rental interest factor		32		28		28		23		15
Allowance for borrowed funds used during construction		14		22		18		14		11
Fixed charges included in the determination of net income		1,025		899		859		799		732
Capitalized interest		75		88		55		40		18
Total fixed charges, as defined	$	1,100	$	987	$	914	$	839	$	750
Ratio of earnings to fixed charges and ratio of earnings to combined fixed charges and preferred stock dividends(a)		3.23		2.91		3.28		3.10		3.13

¾¾¾¾¾¾¾¾¾¾

(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)

	Years Ended December 31,
	2010		2009		2008		2007		2006
	(millions of dollars)
Earnings, as defined:
Net income	$	945	$	831	$	789	$	836	$	802
Income taxes		580		473		443		451		424
Fixed charges included in the determination of net income, as below		382		347		359		325		296
Total earnings, as defined	$	1,907	$	1,651	$	1,591	$	1,612	$	1,522
Fixed charges, as defined:
Interest expense	$	361	$	318	$	334	$	304	$	278
Rental interest factor		8		7		7		7		7
Allowance for borrowed funds used during construction		13		22		18		14		11
Fixed charges included in the determination of net income		382		347		359		325		296
Capitalized interest		3		2		-		-		-
Total fixed charges, as defined	$	385	$	349	$	359	$	325	$	296
Ratio of earnings to fixed charges and ratio of earnings to combined fixed charges and preferred stock dividends(a)		4.95		4.73		4.43		4.96		5.14

¾¾¾¾¾¾¾¾¾¾

(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-21

Exhibit 21

SUBSIDIARIES OF NEXTERA ENERGY, INC.

NextEra Energy, Inc.'s principal subsidiaries as of December 31, 2010 are listed below.

	Subsidiary	State or Jurisdiction of Incorporation
1.	Florida Power & Light Company (100%-owned)	Florida
2.	NextEra Energy Capital Holdings, Inc. (100%-owned)	Florida
3.	NextEra Energy Resources, LLC(a)(b)	Delaware
4.	Palms Insurance Company, Limited(b)	Cayman Islands

¾¾¾¾¾¾¾¾¾¾

(a)	Includes 390 subsidiaries that operate in the United States and 39 subsidiaries that operate in foreign countries in the same line of business as NextEra Energy Resources, LLC.
(b)	100%-owned subsidiary of NextEra Energy Capital Holdings, Inc.

EX-23

Exhibit 23

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in the following Registration Statements of our reports dated February 25, 2011, relating to the consolidated financial statements of NextEra Energy, Inc. and subsidiaries (NextEra Energy) (formerly FPL Group, Inc.) and Florida Power & Light Company and subsidiaries (FPL) and the effectiveness of NextEra Energy's and FPL's internal control over financial reporting, appearing in this Annual Report on Form 10-K of NextEra Energy and FPL for the year ended December 31, 2010:

NextEra Energy, Inc.		Florida Power & Light Company Trust I
Form S-8	No. 33-11631	Form S-3	No. 333-160987-06
Form S-8	No. 33-57673
Form S-8	No. 333-27079	Florida Power & Light Company Trust II
Form S-8	No. 333-88067	Form S-3	No. 333-160987-05
Form S-8	No. 333-114911
Form S-8	No. 333-116501	NextEra Energy Capital Holdings, Inc. (formerly FPL Group Capital Inc)
Form S-3	No. 333-125275	Form S-3	No. 333-160987-08
Form S-8	No. 333-125954
Form S-3	No. 333-129482	FPL Group Capital Trust II
Form S-8	No. 333-130479	Form S-3	No. 333-160987-04
Form S-3	No. 333-160987
Form S-8	No. 333-143739	FPL Group Capital Trust III
Form S-3	No. 333-159011	Form S-3	No. 333-160987-03
FPL Group Trust I
Form S-3	No. 333-160987-02
FPL Group Trust II
Form S-3	No. 333-160987-01
Florida Power & Light Company
Form S-3	No. 333-160987-07

DELOITTE & TOUCHE LLP

Miami, Florida

February 25, 2011

EX-31.A

Exhibit 31(a)

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

I, Lewis Hay, III, certify that:

1.	I have reviewed this Form 10-K for the annual period ended December 31, 2010 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:   February 25, 2011

LEWIS HAY, III

Lewis Hay, III

Chairman and Chief Executive Officer

of NextEra Energy, Inc.

EX-31.B

Exhibit 31(b)

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

I, Armando Pimentel, Jr., certify that:

1.	I have reviewed this Form 10-K for the annual period ended December 31, 2010 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:   February 25, 2011

ARMANDO PIMENTEL, JR.

Armando Pimentel, Jr.

Executive Vice President, Finance

and Chief Financial Officer

of NextEra Energy, Inc.

EX-31.C

Exhibit 31(c)

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

I, Armando J. Olivera, certify that:

1.	I have reviewed this Form 10-K for the annual period ended December 31, 2010 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:   February 25, 2011

ARMANDO J. OLIVERA

Armando J. Olivera

President and Chief Executive Officer

of Florida Power & Light Company

EX-31.D

Exhibit 31(d)

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

I, Armando Pimentel, Jr., certify that:

1.	I have reviewed this Form 10-K for the annual period ended December 31, 2010 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:   February 25, 2011

ARMANDO PIMENTEL, JR.

Armando Pimentel, Jr.

Executive Vice President, Finance

and Chief Financial Officer of

Florida Power & Light Company

EX-32.A

Exhibit 32(a)

Section 1350 Certification

We, Lewis Hay, III and Armando Pimentel, Jr., certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Annual Report on Form 10-K of NextEra Energy, Inc. (NextEra Energy) for the annual period ended December 31, 2010 (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 NextEra Energy.

Dated:   February 25, 2011

LEWIS HAY, III

Lewis Hay, III

Chairman and Chief Executive Officer

of NextEra Energy, Inc.

ARMANDO PIMENTEL, JR.

Armando Pimentel, Jr.

Executive Vice President, Finance and

Chief Financial Officer of NextEra Energy, Inc.

A signed original of this written statement required by Section 906 has been provided to NextEra Energy and will be retained by NextEra Energy 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 NextEra Energy 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, Armando J. Olivera and Armando Pimentel, Jr., certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Annual Report on Form 10-K of Florida Power & Light Company (FPL) for the annual period ended December 31, 2010 (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 FPL.

Dated:   February 25, 2011

ARMANDO J. OLIVERA

Armando J. Olivera

President and Chief Executive Officer of

Florida Power & Light Company

ARMANDO PIMENTEL, JR.

Armando Pimentel, Jr.

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 FPL and will be retained by FPL 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 FPL 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).