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, 2012



Commission File Number	Exact name of registrants as specified in their charters, address of principal executive offices and registrants' telephone number	IRS Employer Identification Number
1-8841	NEXTERA ENERGY, INC.	59-2449419
2-27612	FLORIDA POWER & LIGHT COMPANY 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 o Florida Power & Light Company Yes þ No o

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 o No þ Florida Power & Light Company Yes o 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 o Florida Power & Light Company Yes þ No o

Indicate by check mark whether the registrants have submitted electronically and posted on their corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrants were required to submit and post such files).

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

Indicate by check mark 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 o	Non-Accelerated Filer o	Smaller Reporting Company o
Florida Power & Light Company	Large Accelerated Filer o	Accelerated Filer o	Non-Accelerated Filer þ	Smaller Reporting Company o

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 29, 2012 (based on the closing market price on the Composite Tape on June 29, 2012) was $28,982,338,359.

There was no voting or non-voting common equity of Florida Power & Light Company held by non-affiliates as of June 29, 2012.

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, 2013: 423,867,308 shares.

As of January 31, 2013, 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 2013 Annual Meeting of Shareholders are incorporated by reference in Part III hereof.

________________________

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

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

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DEFINITIONS

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



Term	Meaning
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
AOCI	accumulated other comprehensive income
capacity clause	capacity cost recovery clause, as established by the FPSC
CFTC	U.S. Commodity Futures Trading Commission
CO₂	carbon dioxide
DOE	U.S. Department of Energy
Duane Arnold	Duane Arnold Energy Center
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	fiber-optic telecommunications business
FPSC	Florida Public Service Commission
fuel clause	fuel and purchased power cost recovery clause, as established by the FPSC
GAAP	generally accepted accounting principles in the U.S.
GHG	greenhouse gas(es)
ISO	independent system operator
ITCs	investment tax credits
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
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)
mwh	megawatt-hour(s)
NEE	NextEra Energy, Inc.
NEECH	NextEra Energy Capital Holdings, Inc.
NEER	NextEra Energy Resources, LLC
NEET	NextEra Energy Transmission, LLC
NERC	North American Electric Reliability Corporation
NHT	New Hampshire Transmission, LLC
Note __	Note __ to consolidated financial statements
NOx	nitrogen oxide
NRC	U.S. Nuclear Regulatory Commission
O&M expenses	other operations and maintenance expenses in the consolidated statements of income
OCI	other comprehensive income
OTC	over-the-counter
OTTI	other than temporary impairment
PJM	PJM Interconnection, L.L.C.
PMI	NextEra Energy Power Marketing, LLC
Point Beach	Point Beach Nuclear Power Plant
PTCs	production tax credits
PUCT	Public Utility Commission of Texas
PURPA	Public Utility Regulatory Policies Act of 1978, as amended
PV	photovoltaic
regulatory ROE	return on common equity as determined for regulatory purposes
RFP	request for proposal
ROE	return on common equity
RPS	renewable portfolio standards
RTO	regional transmission organization
Seabrook	Seabrook Station
SEC	U.S. Securities and Exchange Commission
SO₂	sulfur dioxide
U.S.	United States of America
WCEC	FPL's West County Energy Center in western Palm Beach County, Florida

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

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TABLE OF CONTENTS



		Page No.
Definitions		2
Forward-Looking Statements		3
	PART I

Item 1.	Business	4
Item 1A.	Risk Factors	24
Item 1B.	Unresolved Staff Comments	35
Item 2.	Properties	36
Item 3.	Legal Proceedings	39
Item 4.	Mine Safety Disclosures	39
	PART II

Item 5.	Market for Registrants' Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	40
Item 6.	Selected Financial Data	41
Item 7.	Management's Discussion and Analysis of Financial Condition and Results of Operations	42
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	70
Item 8.	Financial Statements and Supplementary Data	71
Item 9.	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	127
Item 9A.	Controls and Procedures	127
Item 9B.	Other Information	127
	PART III

Item 10.	Directors, Executive Officers and Corporate Governance	128
Item 11.	Executive Compensation	128
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	128
Item 13.	Certain Relationships and Related Transactions, and Director Independence	128
Item 14.	Principal Accounting Fees and Services	129
	PART IV

Item 15.	Exhibits, Financial Statement Schedules	130

Signatures		139

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 result, are expected to, will continue, is anticipated, aim, believe, could, should, would, estimated, may, plan, potential, future, projection, goals, target, outlook, predict and intend or words of similar meaning) are not statements of historical facts and may be forward looking. Forward-looking statements involve estimates, assumptions and uncertainties. Accordingly, any such statements are qualified in their entirety by reference to, and are accompanied by, 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 NEE's and/or FPL's operations and financial results, and could cause NEE's and/or FPL's actual results to differ materially from those contained or implied in forward-looking statements made by or on behalf of NEE and/or FPL in this combined Form 10-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 NEE and FPL undertake no obligation to update any forward-looking statement to reflect events or circumstances, including, but not limited to, unanticipated events, after the date on which such statement is made, unless otherwise required by law. New factors emerge from time to time and it is not possible for management to predict all of such factors, nor can it assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained or implied in any forward-looking statement.

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PART I

Item 1. Business

OVERVIEW

NextEra Energy, Inc. (hereafter, NEE) is one of the largest electric power companies in North America, with over 42,000 mw of generating capacity in 26 states in the U.S. and 4 provinces in Canada, and employing approximately 14,800 people as of December 31, 2012. NEE provides retail and wholesale electric services to nearly 5 million customers and owns generation, transmission and distribution facilities to support its services. It also purchases electric power for resale to its customers and provides risk management services related to power and gas consumption for a limited number of customers. NEE is the largest generator in North America of renewable energy from the wind and sun. NEE owns and operates approximately 17% of the installed base of U.S. wind power production capacity and operates approximately 14% of the installed base of U.S. utility-scale solar power production capacity as of December 31, 2012. NEE also owns and operates one of the largest fleets of nuclear power stations in the U.S., with eight reactors at five sites located in four states, representing approximately 6% of U.S. nuclear power electric generating capacity as of December 31, 2012. NEE's business strategy has emphasized the development, acquisition and operation of renewables, nuclear and natural gas-fired generation facilities in response to long-term federal policy trends supportive of zero and low air emissions sources of power. NEE's generation fleet has significantly lower rates of emissions of CO₂, SO₂ and NOx than the average rates of the U.S. electric power industry with approximately 97% of its 2012 generation, measured by mwh produced, coming from renewables, nuclear and natural gas-fired facilities. Certain environmental attributes of NEE's electric generating facilities, such as renewable energy credits, emissions reductions, offsets, allowances and the avoided emission of GHG pollutants, have been or likely will be sold or transferred to third parties, who are solely entitled to the reporting rights and ownership of the environmental attributes.

NEE was incorporated in 1984 under the laws of Florida and conducts its operations principally through two wholly-owned subsidiaries, Florida Power & Light Company (hereafter, FPL) and NextEra Energy Resources, LLC (hereafter, NEER). NextEra Energy Capital Holdings, Inc. (hereafter, NEECH), another wholly-owned subsidiary of NEE, owns and provides funding for NEER's and NEE's other operating subsidiaries, other than FPL and its subsidiaries. NEE's two principal businesses also constitute NEE's reportable segments for financial reporting purposes.

FPL is a rate-regulated electric utility engaged primarily in the generation, transmission, distribution and sale of electric energy in Florida. FPL is the largest electric utility in the state of Florida and one of the largest electric utilities in the U.S. based on retail mwh sales. FPL is vertically integrated, with approximately 24,100 mw of generating capacity as of December 31, 2012. FPL's investments in its infrastructure since 2001, such as modernizing less efficient generating plants to produce more energy with less fuel and fewer air emissions, and upgrading its transmission and distribution systems to deliver service reliability that is the best of the Florida investor-owned utilities, have provided significant benefits to FPL's customers, all while providing residential and commercial bills that were among the lowest in Florida and below the national average based on a rate per kwh as of July 2012. With approximately 95% of its power generation coming from natural gas, nuclear and solar, FPL is also one of the cleanest electric utilities in the nation. Based on 2012 information, FPL's emissions rates for CO₂, SO₂ and NOx were 29%, 91% and 67% lower, respectively, than the average rates of the U.S. electric power industry.

NEER is one of the largest wholesale generators of electric power in the U.S., with over 18,100 mw of generating capacity across 24 states and 4 Canadian provinces as of December 31, 2012. NEER produces the majority of its electricity from clean and renewable sources, including wind and solar. NEER also provides full energy and capacity requirements services, engages in power and gas marketing and trading activities, participates in natural gas production and pipeline infrastructure development and owns a retail electricity provider.

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NEECH's other business activities are primarily conducted through NEET and FPL FiberNet. NEET conducts its operations principally through two wholly-owned subsidiaries, Lone Star, a rate-regulated transmission service provider in Texas, and NHT, a rate-regulated transmission owner in New Hampshire. FPL FiberNet delivers wholesale and enterprise telecommunications services in Florida and certain areas of the South Central U.S.

NEE seeks to create value in its two principal businesses by meeting its customers' needs more economically and more reliably than its competitors, as described in more detail in the following sections. NEE's strategy has resulted in profitable growth over sustained periods at both FPL and NEER. Management seeks to grow each business in a manner consistent with the varying opportunities open to it and does not maintain any specific goal as to the relative size of the two businesses. However, management believes that the diversification and balance represented by FPL and NEER is a valuable characteristic of the enterprise. FPL and NEER, as well as other NEE subsidiaries, share common support functions with the objective of lowering costs and creating efficiencies for their businesses.

NEE'S OPERATING SUBSIDIARIES

I. FPL

FPL was incorporated under the laws of Florida in 1925, and is a wholly-owned subsidiary of NEE. FPL is a rate-regulated electric utility and is the largest electric utility in the state of Florida and one of the largest electric utilities in the U.S. based on retail mwh sales. FPL, with 24,057 mw of generating capacity at December 31, 2012, supplies electric service throughout most of the east and lower west coasts of Florida, serving more than 8.9 million people through approximately 4.6 million customer accounts. At December 31, 2012, FPL's service territory and plant locations are as follows (see Item 2 - Generating Facilities):

FRANCHISE AGREEMENTS AND COMPETITION

FPL's service to its retail customers is provided primarily under franchise agreements negotiated with municipalities or counties. Alternatively, municipalities and counties may form their own utility companies to provide service to their residents. In a few cases, an FPL franchise agreement provides the municipality or county the right to buy the distribution assets serving local residents at the end of the agreement. However, during the term of a franchise agreement, which is typically 30 years, the municipality or county agrees not to form its own utility, and FPL has the right to offer electric service to residents. FPL currently holds 177 franchise agreements with various municipalities and counties in Florida with varying expiration dates through 2042. Two of these franchise agreements expire in 2013, seven expire in 2014 and 168 expire during the period 2015 through 2042. These franchise agreements cover approximately 86% of FPL's retail customer base in Florida. Negotiations are ongoing to renew the franchise agreements that expire in 2013 and 2014. FPL considers its franchises to be adequate for the conduct of its business. FPL also provides service to 12 other municipalities and to 22 unincorporated areas within its service area without franchise agreements pursuant to the general obligation to serve as a public utility, relying upon Florida law for access to public rights of way.

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Because any retail customer may elect to provide his/her own electric services, FPL effectively must compete for an individual customer's business. As a practical matter, few customers provide their own service at the present time since FPL's cost of service is generally substantially lower than the cost of self-generation for the vast majority of customers. Changing technology and economic conditions could alter the favorable relative cost position that FPL currently enjoys; however, FPL seeks as a matter of strategy to ensure that it delivers superior value, in the form of high reliability, low bills and excellent customer service.

FPL also 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. In each of 2012, 2011 and 2010, operating revenues from wholesale and industrial customers combined represented approximately 3% of FPL's total operating revenues.

The FPSC promotes cost competitiveness in the building of new steam and solar generating capacity by requiring investor-owned electric utilities, including FPL, to issue an 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 purchased power agreement with the selected bidder and request that the FPSC approve the terms of the purchased power 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 FPL Sources of Generation - Nuclear Operations below regarding FPL's planned two additional nuclear units at Turkey Point.

CUSTOMERS AND REVENUE

FPL's primary source of operating revenues is from its retail customer base; it also serves a limited number of wholesale customers within Florida. The percentage of FPL's operating revenues and customer accounts by customer class were as follows:

For both retail and wholesale customers, the prices (or rates) that FPL may charge are controlled by regulation, by the FPSC in the case of retail customers, and by the FERC in the case of wholesale customers. In general, under U.S. and Florida law, regulated rates are intended to cover the cost of providing service, including an appropriate rate of return on capital employed. However, the regulatory bodies have authority to determine the relevant cost of providing service and the appropriate rate of return on capital employed and there can be no guarantee that FPL will be able to earn any particular rate of return or recover all of its costs through regulated rates. See the discussion of regulation at FPL Regulation below.

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FPL seeks to maintain attractive rates for its customers. Since rates are largely cost-based, maintaining low rates requires a strategy focused on developing and maintaining a low cost position. A common benchmark used in the electric power industry for comparing rates across companies is the cost per 1,000 kwh of consumption per month for a residential customer. FPL's 2012 average cost per 1,000 kwh of monthly residential usage was the lowest of the 55 electric utilities within Florida as indicated below:

TRANSMISSION AND DISTRIBUTION

FPL provides service to its customers through an integrated transmission and distribution system that links its generation facilities to its customers. FPL also maintains interconnection facilities with neighboring utilities and wholesale power providers, enabling it to buy and sell wholesale electricity outside its service territory and to enhance the reliability of its own network and support the reliability of neighboring networks. FPL's transmission system carries high voltage electricity from its generating facilities to substations where the electricity is stepped down to lower voltage levels and is sent through the distribution system to its customers.

A key element of FPL's strategy is to provide highly reliable service to its customers. The transmission and distribution system is susceptible to interruptions or outages from a wide variety of sources including weather, animal interference, traffic accidents, equipment failure and many others, and FPL seeks to reduce or eliminate outages where economically practical and to restore service rapidly when outages occur. A common industry benchmark for transmission and distribution system reliability is the system average interruption duration index (SAIDI), which represents the number of minutes the average customer is without power during a time period. For the five years 2007-2011, FPL's average annual SAIDI was the best of the investor-owned utilities in Florida.

FPL SYSTEM CAPABILITY AND LOAD

At December 31, 2012, FPL's resources for serving load consisted of 26,020 mw, of which 24,057 mw were from FPL-owned facilities (see Item 2 - Generating Facilities) and 1,963 mw were available through purchased power agreements (see FPL Sources of Generation - Purchased Power below). 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 resources available at the time of this peak to meet customer demand.

FPL's projected reserve margin for the summer of 2013 is approximately 28%. This reserve margin is expected to be achieved through the combination of available output from FPL's active generating units, purchased power agreements and the capability to reduce peak demand through the implementation of demand side management programs, including load management which was estimated at December 31, 2012 to be capable of reducing demand by 1,865 mw, and energy efficiency and conservation programs. See FPL Sources of Generation - Fossil Operations and Nuclear Operations below regarding generation projects currently under construction.

FPL SOURCES OF GENERATION

FPL relies upon a mix of fuel sources for its generating facilities, along with purchased power, in order to maintain the flexibility to achieve a more economical fuel mix by responding to market and industry developments. See descriptions of fossil, nuclear and solar operations below and a listing of FPL's generating facilities in Item 2 - Generating Facilities.

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FPL's 2012 fuel mix based on mwh produced, including purchased power, was as follows:

During 2012, nuclear generation was lower than in 2011 as a result of outages related to a generation uprate project at FPL's nuclear units.

Fossil Operations (Natural Gas, Coal and Oil)

At December 31, 2012, FPL owned and operated 73 units that used fossil fuels such as natural gas and/or oil, and had a joint ownership interest in three coal units, which combined provided 20,696 mw of generating capacity for FPL. These fossil units are out of service from time to time for routine maintenance or on standby during periods of reduced electricity demand.

FPL's natural gas plants require natural gas transportation, supply and storage. FPL has firm transportation contracts in place with five different transportation suppliers with expiration dates ranging from 2015 to 2036 that together are expected to satisfy substantially all of the currently anticipated needs for natural gas transportation through 2016. To the extent desirable, FPL also purchases interruptible natural gas transportation service from these natural gas transportation 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 an agreement for the storage of natural gas that expires in 2014. See Note 13 - Contracts. With respect to its oil plants, FPL obtains its fuel requirements in the spot market.

In December 2012, FPL issued an RFP for an approximately 700-mile natural gas pipeline that will help FPL identify and evaluate options for new natural gas transportation infrastructure in Florida to meet the growing need for natural gas power. The proposed pipeline will be composed of two segments and be operational beginning in 2017. The upstream segment will originate at an existing hub in western Alabama and end at a new hub to be built in Central Florida that will allow the new pipeline to interconnect with peninsular Florida's two existing natural gas pipelines. The downstream segment will originate at the new Central Florida hub and end in Martin County, Florida at FPL's Martin power plant. FPL plans to propose a self-build option for the downstream segment of the pipeline, which, if selected, is expected to be built, owned and operated by a FERC-regulated affiliate. The bids are due in April 2013 with the winning proposal(s) expected to be selected by the end of June 2013. The pipeline will be subject to regulatory approvals.

St. Johns River Power Park (SJRPP) Units Nos. 1 and 2, in which FPL has a joint ownership interest, has a coal supply and transportation contract for a portion of the 2013 and 2014 fuel needs for those units. All of the transportation requirements and a portion of the coal supply needs for Scherer Unit No. 4, the other coal unit in which FPL has a joint ownership interest, are covered by a series of annual and long-term contracts. The remaining fuel requirements for these units will be obtained in the spot market. See Note 13 - Contracts.

Modernization Projects. FPL is in the process of modernizing its Cape Canaveral, Riviera Beach and Port Everglades power plants to high-efficiency natural gas-fired units that will provide approximately 1,200 mw, 1,200 mw and 1,280 mw of capacity, respectively, and be placed in service by June 2013, June 2014 and mid-2016, respectively. In May 2012, the Florida Industrial Power Users Group appealed the FPSC's order approving the Port Everglades modernization, which appeal will be heard by the Florida Supreme Court.

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Nuclear Operations

At December 31, 2012, FPL owned, or had undivided interests in, and operated the following four nuclear units with a total net generating capacity of 3,326 mw.



Facility	mw	Operating License Expiration Dates
St. Lucie Unit No. 1	981	2036
St. Lucie Unit No. 2	843	2043
Turkey Point Unit No. 3	809	2032
Turkey Point Unit No. 4	693	2033

FPL has several contracts for the supply of uranium and the conversion, enrichment and fabrication of nuclear fuel with expiration dates ranging from June 2013 through 2023. See Note 13 - Contracts. NRC 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 applicable 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 commencing in 2043.

Projects to Add Additional Capacity. FPL is in the final stages of a generation uprate project which is expected to add at least 510 mw of capacity at its existing nuclear units at St. Lucie and Turkey Point, which are expected to result in significant fuel cost savings compared to other sources of generation over the lives of the units. As of December 31, 2012, approximately 395 mw of the additional capacity were in service; the remaining amount of additional capacity is projected to be placed in service in the spring of 2013. As part of the conditions of certification by the FDEP for the Turkey Point units, 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 prior to and after the additional capacity is placed in service. Data for the first two years has been collected and provided to the FDEP. 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. Additionally, the issuance of a combined operating license by the NRC may be delayed due to required revisions to the NRC's Waste Confidence Rule concerning the storage of spent nuclear fuel after reactor operation, which revisions are not expected to be finalized before late 2014.

Nuclear Unit Scheduled Refueling Outages. FPL's 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 variable lengths of time. The duration is longer for expanded scope outages, one of which is expected to be completed in the spring of 2013 at Turkey Point Unit No. 4. The following table summarizes each unit's current or next scheduled refueling outage:



Facility		Beginning of Current or Next Scheduled Refueling Outage
St. Lucie Unit No. 1		September 2013
St. Lucie Unit No. 2		March 2014
Turkey Point Unit No. 3		January 2014
Turkey Point Unit No. 4		November 2012

Disposition of Spent Nuclear Fuel. FPL's nuclear facilities use both on-site storage pools and dry storage casks to store spent nuclear fuel generated by these facilities, which are expected to allow FPL to store spent nuclear fuel at these facilities through license expiration.

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 nuclear units.

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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 DOE did not meet its statutory obligation for disposal of spent nuclear fuel under the Nuclear Waste Policy Act. In 2009, FPL and certain of FPL's nuclear plant joint owners entered into 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 are reimbursable by the U.S. government on an annual basis. In a separate lawsuit filed in 2011, FPL joined the Nuclear Energy Institute and several other nuclear plant owners and operators (Petitioners) in petitioning the U.S. Court of Appeals for the District of Columbia (D.C. Circuit) to challenge the DOE's decision to continue to collect the nuclear waste fee. In June 2012, the D.C. Circuit held that the DOE's fee adequacy determination was legally defective but remanded the case to the DOE to revise its determination while retaining jurisdiction over the matter. In January 2013, the DOE issued its revised fee adequacy determination concluding that the nuclear waste fee was adequate, at which time the Petitioners filed a motion to reopen the case with the D.C. Circuit. FPL will continue to pay fees to the U.S. government's nuclear waste fund pending further action by the D.C. Circuit.

In March 2010, the DOE filed a motion with the NRC to withdraw its license application for a nuclear waste repository at Yucca Mountain. The DOE's withdrawal motion has been challenged and is being litigated before the NRC and the D.C. Circuit. In light of the government's decision not to proceed with the Yucca Mountain repository project, the DOE 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 spent nuclear fuel and high-level radioactive waste. In January 2012, the BRC issued its report and recommendations which includes a consent-based approach, working with all affected units of government, to site future nuclear waste management facilities; creation of a new organization, independent of the DOE, dedicated solely to assuring the safe storage and ultimate disposal of spent nuclear fuel and high-level radioactive waste; providing access to the U.S. government's nuclear waste fund for the purpose of nuclear waste storage and disposal; and initiating prompt efforts to develop geologic disposal facilities, consolidated interim storage facilities and transportation to those facilities. In January 2013, the DOE issued a strategy document for implementing the BRC recommendations. The strategy document outlines, among other things, long-term plans for a new management organization to handle spent fuel storage and disposal activities, development of new interim storage facilities and several possible funding reforms, including accessing the nuclear waste fund for funding these activities. Each of these steps will require new federal legislation.

Nuclear Regulatory Developments. As a result of the impact of the 2011 earthquake and tsunami on nuclear facilities in Japan, the NRC conducted a comprehensive review of processes and regulations relating to nuclear facilities in the U.S. to determine whether it should make additional improvements to its regulatory system and policies. In March 2012, based on the review, the NRC established, among other things, the following actions which: 1) require each nuclear site to purchase portable equipment and revise procedures to address multi-unit events, provide reliable spent fuel pool instrumentation and enhance containment venting capabilities for boiling water reactors (FPL's nuclear units do not use boiling water reactors; see NEER - Generation and Other Operations - Nuclear Facilities - Nuclear Regulatory Developments); 2) request each site to re-evaluate its seismic and flood protection designs in light of current requirements and identify any areas for improvement; and 3) require enhancements relating to extended periods of loss of alternating current power, emergency preparedness and spent fuel pool cooling capabilities. The NRC also prescribed a timeline for implementation of the actions with completion by the end of 2016. FPL is currently reviewing various orders and requests for information being issued by the NRC and assessing the potential financial and operational impacts on its nuclear units, which could be significant. FPL's preliminary estimate of the cost to complete the actions described above is included in estimated capital expenditures. See Note 13 - Commitments.

The lessons learned from the events in Japan and the results of the NRC's actions will, among other things, result in new licensing and safety-related requirements for U.S. nuclear facilities. Any new requirements could, among other things, impact future licensing and operations of U.S. nuclear facilities, including FPL's existing nuclear facilities and the NRC approval of two additional nuclear units at FPL's Turkey Point site, and could, among other things, result in increased cost and capital expenditures associated with the operation and maintenance of FPL's nuclear units. Third parties have requested that the NRC, among other things, suspend the approval of nuclear license extensions and new licenses, including approval of licenses for two additional nuclear units at FPL's Turkey Point site. It is uncertain how and when the NRC will respond to the requests or other requests it may receive.

Solar Operations

Solar generation can be provided primarily through two conventions: utility-owned and customer-owned. In utility-owned solar generation, the energy generated goes directly to the transmission grid, whereas customer-owned solar generation goes directly to the location it is serving. There are two principal solar technologies used for utility-scale projects: photovoltaic and thermal. FPL placed its first utility-scale solar generating facility into service in 2009, a 25 mw solar PV facility in DeSoto County, Florida, and placed two additional solar generating facilities in service in 2010, a 10 mw solar PV facility in Brevard County, Florida and a 75 mw solar thermal facility in Martin County, Florida.

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Purchased Power

In addition to owning generation facilities, FPL also purchases electricity from other utilities to meet customer demand through long- and short-term purchased power agreements. As of December 31, 2012, FPL's long-term purchased power agreements provided for the purchase of approximately 1,963 mw of power with expiration dates ranging from 2015 through 2032. See Note 13 - Contracts. FPL also procures short-term capacity for both economic and reliability purposes.

FPL 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 (primarily 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 FPL Regulation - FPL Rate Regulation below, Management's Discussion - Energy Marketing and Trading and Market Risk Sensitivity and Note 3.

FPL REGULATION

FPL's operations are subject to regulation by a number of federal, state and other organizations, including, but not limited to, the following:


•	the FPSC, which has jurisdiction over retail rates, service territory, issuances of securities, planning, siting and construction of facilities, among other things;


•	the FERC, which oversees the acquisition and disposition of facilities, transmission services and wholesale purchases and sales of electric energy, among other things;


•	the NERC, which, through its regional entities, establishes and enforces mandatory reliability standards, subject to approval by the FERC, to ensure the reliability of the U.S. electric transmission and generation system and to prevent major system blackouts;


•	the NRC, which has jurisdiction over the operation of FPL's nuclear power plants through the issuance of operating licenses, rules, regulations and orders (see FPL Sources of Generation - Nuclear Operations above); and


•	the EPA, which has the responsibility to maintain and enforce national standards under a variety of environmental laws. The EPA also works with industries and all levels of government, including federal and state governments, in a wide variety of voluntary pollution prevention programs and energy conservation efforts.

FPL Rate Regulation

The FPSC sets rates at a level that is intended to allow FPL the opportunity to collect from retail customers total revenues (revenue requirements) equal to FPL's 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 monthly by FPL with the FPSC. The FPSC does not provide assurance that any ROE will be achieved. Base rates are determined in rate proceedings or through negotiated settlements of those proceedings. Proceedings can occur at the initiative of FPL or upon action by the FPSC. Base rates remain in effect until new base rates are approved by the FPSC.

Rates Effective January 2013 - December 2016 - In January 2013, the FPSC issued a final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2012 rate agreement). Key elements of the 2012 rate agreement, which is effective from January 2013 through December 2016, include, among other things, the following:


•	New retail base rates and charges were established in January 2013 resulting in an increase in retail base revenues of $350 million on an annualized basis.


•	FPL's allowed regulatory ROE will be 10.50%, with a range of plus or minus 100 basis points. If FPL's earned regulatory ROE falls below 9.50%, FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.50%, any party to the 2012 rate agreement other than FPL may seek a review of FPL's retail base rates.


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

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•	Cost recovery of WCEC Unit No. 3, which was placed in service in May 2011, will continue to occur through the capacity clause; however, such recovery will not be limited to the projected annual fuel cost savings as was the case in the previous rate agreement discussed below.

•

Subject to certain conditions, FPL must amortize, over the term of the 2012 rate agreement, a depreciation reserve surplus remaining at the end of 2012 under the 2010 FPSC rate order discussed below (approximately $224 million) and may amortize a portion of FPL's fossil dismantlement reserve up to a maximum of $176 million (collectively, the reserve), provided that in any year of the 2012 rate agreement, FPL must amortize at least enough reserve to maintain a 9.50% earned regulatory ROE but may not amortize any reserve that would result in an earned regulatory ROE in excess of 11.50%.

•

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

On February 7, 2013, the Office of Public Counsel filed a notice of appeal to the Florida Supreme Court of the FPSC's final order regarding the 2012 rate agreement.

Rates Effective March 2010 - December 2012 - Effective March 1, 2010, pursuant to an FPSC final order (2010 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 2010 FPSC rate order, among other things, also established a regulatory ROE of 10.0% with a range of plus or minus 100 basis points. In February 2011, the FPSC issued a final order approving a stipulation and settlement agreement between FPL and principal parties in FPL's 2009 rate case (2010 rate agreement). The 2010 rate agreement, which was effective through December 31, 2012, provided for, among other things, a reduction in depreciation expense (surplus depreciation credit) 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 total cap of $776 million over the course of the 2010 rate agreement, provided that in any year of the 2010 rate agreement FPL was required to use enough surplus depreciation credit to maintain an earned regulatory ROE within the range of 9.0% - 11.0%. The 2010 rate agreement also permitted incremental cost recovery through FPL's capacity clause for WCEC Unit No. 3 up to the amount of the projected annual fuel savings for customers. See Cost Recovery Clauses below for additional information regarding the capacity clause.

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 costs, certain construction-related costs and conservation and certain environmental-related costs. 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 true-up adjustments to reflect the estimated over or under recovery of costs for the current and prior periods. An adjustment to the levelized charges may be approved during the course of a year to reflect revised estimates.

Fuel costs are recovered from customers through the fuel clause, the most significant of the cost recovery clauses. FPL uses a risk management fuel procurement program which has been approved by the FPSC. The FPSC reviews the program activities and results for prudence annually as part of its 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 FPL Energy Marketing and Trading above, Management's Discussion - FPL: Results of Operations, 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. In accordance with the FPSC's nuclear cost recovery rule, FPL also recovers pre-construction costs and carrying charges (equal to a fixed pretax AFUDC rate) on construction costs for new nuclear capacity through the capacity clause. As property related to the new nuclear capacity goes into service, construction costs and a return on investment are recovered through base rate increases effective beginning the following January. See FPL Sources of Generation - Nuclear Operations above. In accordance with the 2012 and 2010 rate agreements, cost recovery for WCEC Unit No. 3 is permitted during the term of the agreements through FPL's capacity clause and is reported as retail base revenues.

Costs associated with implementing energy conservation programs are recovered from customers through the energy conservation cost recovery clause. 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 compliance cost recovery clause (environmental clause).

The FPSC has the authority to disallow recovery of costs that it considers excessive or imprudently incurred. These 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.

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FERC

The Federal Power Act gives the FERC exclusive ratemaking jurisdiction over wholesale sales of electricity and the transmission of electricity in interstate commerce. Pursuant to the Federal Power Act, electric utilities must maintain tariffs and rate schedules on file with the FERC which govern the rates, terms and conditions for the provision of FERC-jurisdictional wholesale power and transmission services. The Federal Power Act also gives the FERC authority to certify and oversee a national electric reliability organization with authority to develop mandatory reliability standards applicable to all users, owners and operators of bulk-power systems. The FERC also approves reliability standards and makes them enforceable. See NERC below. Electric utilities are subject to accounting, record-keeping and reporting requirements administered by the FERC. The FERC also places certain limitations on transactions between electric utilities and their affiliates.

NERC

The NERC has been certified by the FERC as the national electric reliability organization. The NERC ensures the reliability and security of the North American bulk power system. The NERC's regional entities establish requirements, approved by the FERC, for reliable operation and maintenance of power generation facilities and transmission systems. FPL is subject to these reliability requirements and incurs costs to ensure compliance with continually heightened requirements, and can incur significant penalties for failing to comply with them. Each NERC region reports seasonally and annually on the status of generation and transmission in each region.

FPL Environmental Regulation

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

FPL EMPLOYEES

FPL had approximately 9,700 employees at December 31, 2012. 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, 2014.

II. NEER

NEER was formed in 1998 to aggregate NEE's competitive energy businesses. It is a limited liability company organized under the laws of Delaware and is a wholly-owned subsidiary of NEECH. Through its subsidiaries, NEER currently owns, develops, constructs, manages and operates electric generating facilities in wholesale energy markets primarily in the U.S., as well as in Canada and Spain. See Note 14. NEER is one of the largest wholesale generators of electric power in the U.S., with 18,122 mw of generating capacity across 24 states and 4 Canadian provinces as of December 31, 2012. NEER produces the majority of its electricity from clean and renewable sources as described more fully below. NEER is the largest owner of wind and utility-scale solar energy projects in North America. Since 2002, NEER has more than doubled its generating capacity, primarily through the development of new wind projects and acquisition of nuclear projects.

NEER engages in power and gas marketing and trading activities, including entering into financial and physical contracts, to hedge the production from its generating assets that is not sold under long-term power supply agreements. These activities include providing full energy and capacity requirements services primarily to distribution utilities in certain markets and offering customized power and gas and related risk management services to wholesale customers. NEER also participates in natural gas production through non-operating ownership interests and pipeline infrastructure development, hereafter referred to as the gas infrastructure business, and owns a retail electricity provider serving customers in 13 states and the District of Columbia.

MARKETS AND COMPETITION

Electricity markets in the U.S. are regional and diverse in character. All are extensively regulated, and competition in these markets is shaped and constrained by regulation. The nature of the products offered varies based on the specifics of regulation in each region. Generally, in addition to the natural constraints on pricing freedom presented by competition, NEER may also face specific constraints in the form of price caps, or maximum allowed prices, for certain products. NEER's ability to sell the output of its generation facilities is also constrained by available transmission capacity, which can vary from time to time and can have a significant impact on pricing.

The degree and nature of competition that NEER faces is different in wholesale markets and in retail markets. Approximately 90% of NEER's revenue is derived from wholesale markets.

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Wholesale power generation is a capital-intensive, commodity-driven business with numerous industry participants. NEER primarily competes on the basis of price, but believes the green attributes of NEER's generating assets, its creditworthiness and its ability to offer and manage customized risk solutions to wholesale customers are competitive advantages. Wholesale power generation is a regional business that is currently highly fragmented relative to many other commodity industries and diverse in terms of industry structure. As such, there is a wide variation in terms of the capabilities, resources, nature and identity of the companies NEER competes with depending on the market. In wholesale markets, customers' needs are met through a variety of means, including long-term bilateral contracts, standardized bilateral products such as full requirements service and customized supply and risk management services.

In general, U.S. electricity markets encompass three classes of product: energy, capacity and ancillary services. Energy services relate to the physical delivery of power; capacity services relate to the availability of mw capacity of a power generation asset; and ancillary services are other services related to power generation assets, such as load regulation and spinning and non-spinning reserves. The exact nature of these classes of product is defined in part by regional tariffs. Not all regions have a capacity product class, and the specific definitions of ancillary services vary from region to region.

RTOs and ISOs exist in a number of regions within which NEER operates to coordinate generation and transmission across wide geographic areas and to run markets. NEER also has operations that fall within the Western Electricity Coordinating Council reliability region that are not under the jurisdiction of an established RTO or ISO. 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. NEER has operations that fall within the following RTOs and ISOs:


•	Alberta Electric System Operator


•	California Independent System Operator


•	ERCOT


•	Independent Electricity System Operator (in Ontario)


•	ISO New England (ISO-NE)


•	Midwest Independent Transmission System Operator (MISO)


•	New York Independent System Operator (NYISO)


•	PJM


•	Southwest Power Pool

NEER competes in different regions to different degrees, but in general it seeks to enter into long-term bilateral contracts for the full output of its generating facilities, and approximately 58% of NEER's generating capacity is fully committed under long-term contracts. Where long-term contracts are not in effect, NEER sells the output of its facilities into daily spot markets. In such cases, NEER will frequently enter into shorter term bilateral contracts, typically but not always of one to three years duration, to hedge the price risk associated with selling into a daily spot market. Such bilateral contracts, which may be hedges either for physical delivery or for financial (pricing) offset, may only protect a portion of the revenue that NEER expects to derive from the associated generation facility and may not qualify for hedge accounting under GAAP. Contracts that serve the economic purpose of hedging some portion of the expected revenue of a generation facility but are not recorded as hedges under GAAP are referred to as “non-qualifying hedges” for adjusted earnings purposes. See Management's Discussion - Overview.

The NEER wind generation portfolio produces renewable energy credits (RECs) which are typically sold along with the energy from the plants under long-term contracts. A small portion of the wind portfolio generation is sold under short-term contracts and the RECs and other environmental attributes may be sold separately.

While the majority of NEER's revenue is derived from the output of its generating facilities, NEER is also an active competitor in several regions in the wholesale full requirements business and in providing structured and customized power and gas products and services to a variety of customers. In the full requirements service, the supplier agrees to meet the customer's needs for a full range of products for every hour of the day for a fixed period of time, thereby assuming the risk of fluctuations in the customer's volume requirements.

The deregulated retail energy business is typically a highly competitive business. In general, competition in the retail energy business is on the basis of price, service, brand image, product offerings and market perceptions of creditworthiness. Electricity is sold pursuant to a variety of product types, including fixed, indexed and renewable products, and customers elect terms of service typically ranging from one month to five years. Retail energy rates are market-based, and not subject to traditional cost-of-service regulation by public service commissions. Non-affiliated transmission and distribution service companies provide, on a non-discriminatory basis, the wires and metering services necessary to deliver service to customers. Subsidiaries of NEER compete in certain states for retail customers, which can be divided into two principal segments: residential and commercial and industrial (C&I). Residential customers largely require only energy services, which may be purchased on a month-to-month basis or under a multi-year contract. Large C&I customers share many of the same characteristics as wholesale utility customers and may require similarly customized and structured products.

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In general, competitive retail electric providers are exposed to both volume and price risk: customers' volumes will vary, and competitive retail providers are committed to supplying the customer's full needs at all times and are therefore responsible for purchases in wholesale markets to meet those needs; and wholesale prices will fluctuate in ways that do not necessarily match the retail prices committed to the customer.

Expanded competition in a frequently changing regulatory environment presents both opportunities and risks for NEER. Opportunities exist for the selective acquisition of generation assets and for the construction and operation of efficient facilities that can sell power in competitive markets. NEER 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 facilities.

GENERATION AND OTHER OPERATIONS

The vast majority of NEER's revenue is derived from selling the products (energy, capacity, RECs and ancillary services) produced by its own generating facilities. However, NEER may combine purchases of relevant products in wholesale markets with products produced by its own generating facilities in order to meet particular customers' needs.

At December 31, 2012, the locations of NEER's generation facilities in North America are as follows:

At December 31, 2012, NEER managed or participated in the management of essentially all of its generation projects in which it has an ownership interest.

NEER categorizes its portfolio in a number of different ways for different business purposes. See a listing of NEER's generating facilities in Item 2 - Generating Facilities. The following combination of the presence/absence of long-term contracts, fuel/technology and region is a common presentation that NEE has used in communicating its business:

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Contracted, Merchant and Other Operations

NEER's portfolio of operations based on the presence/absence of long-term contracts and other operations is described below.

Contracted Assets. Contracted assets are projects with long-term power sales agreements for substantially all of their output and certain wind assets where long-term power contracts are expected to be executed. At December 31, 2012, NEER had 11,039 mw of contracted assets, substantially all of which have long-term power contracts. Essentially all of the output of these contracted assets were under power sales agreements, with a weighted-average remaining contract life of approximately 15 years, and have firm fuel and transportation agreements with expiration dates ranging from March 2013 through 2022. See Note 13 - Contracts. Approximately 8,213 mw of this capacity is wind generation and 1,621 mw of this capacity is nuclear generation. The remaining 1,205 mw use a variety of fuels and technologies such as natural gas, oil and solar.

Merchant Assets. Merchant assets are projects that do not have long-term power sales agreements to sell their output, or, in the case of certain wind assets, are not expected to have long-term power contracts, and therefore require active marketing and hedging. At December 31, 2012, NEER's portfolio of merchant assets consists of 7,083 mw of owned wind, nuclear, natural gas, oil, solar and hydro generating facilities (see NEER Fuel/Technology Mix - Other Assets below), including 846 mw of peak generating facilities. Approximately 60% (based on net mw capacity) of the natural gas-fueled merchant assets have natural gas transportation agreements to provide for fluctuating natural gas requirements. See Note 13 - Contracts. Derivative instruments (primarily swaps, options, futures and forwards) are generally 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, credit and operational risks.

Other. NEER's operations also include the gas infrastructure business and the customer supply and proprietary power and gas trading businesses. At December 31, 2012, the gas infrastructure business had non-operating investments located in shale formations primarily in Texas, Oklahoma, Wyoming, North Dakota and Louisiana. Also, see NEER Customer Supply and Proprietary Power and Gas Trading below.

NEER Fuel/Technology Mix

NEER's generating output is produced using a variety of fuel sources as further described below.

Wind Facilities

At December 31, 2012, NEER had ownership interests in wind generating facilities with a total capacity of 10,057 mw (net ownership). NEER operates substantially all of these wind facilities, which are located in 19 states and Canada. During 2012, NEER added approximately 1,520 mw of new wind generation and sold a wind facility with 30 mw of generating capacity. NEER is currently committed to add approximately 775 mw of new wind generation during the period 2013 to 2015, primarily in Canada. See Policy Incentives for Renewable Energy Projects for additional discussion of NEER's expectations regarding wind development and construction.

Natural Gas Facilities

At December 31, 2012, NEER had 3,991 mw of natural gas assets. NEER owns and operates 1,004 mw of natural gas-fired generation from contracted assets located throughout the Northeast.

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Nuclear Facilities

At December 31, 2012, NEER owned, or had undivided interests in, and operated the following four nuclear units with a total net generating capacity of 2,721 mw.



Facility	Location	mw	Portfolio Category	Operating License Expiration Dates
Seabrook	New Hampshire	1,100	Merchant	2030	^(a)
Duane Arnold	Iowa	431	Contracted^(b)	2034
Point Beach Unit No. 1	Wisconsin	595	Contracted^(c)	2030
Point Beach Unit No. 2	Wisconsin	595	Contracted^(c)	2033

______________________


(a)	In 2010, NEER filed an application with the NRC to renew Seabrook's operating license for an additional 20 years, which license renewal may be delayed due to required revisions to the NRC's Waste Confidence Rule which are not expected to be finalized before late 2014.


(b)	NEER sells substantially all of its share of the output of Duane Arnold under a long-term contract expiring in February 2014. Upon expiration of that contract, NEER will sell all of its share of the output of Duane Arnold under a long-term contract expiring in February 2025.


(c)	NEER sells all of the output of Point Beach Units Nos. 1 and 2 under long-term contracts through the current operating license terms.

NEER's nuclear facilities have several contracts for the supply of uranium and conversion, enrichment and fabrication of nuclear fuel with expiration dates ranging from March 2013 through 2022. See Note 13 - Contracts. NEER 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. NRC regulations require plant owners to submit a plan for decontamination and decommissioning five years before the projected end of plant operation.

Nuclear Unit Scheduled Refueling Outages. NEER's 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 variable lengths of time. The following table summarizes the next scheduled refueling outages:



Facility		Next Scheduled Refueling Outage
Seabrook		April 2014
Duane Arnold		October 2014
Point Beach Unit No. 1		March 2013
Point Beach Unit No. 2		March 2014

Disposition of Spent Nuclear Fuel. NEER's nuclear facilities use both on-site storage pools and dry storage casks to store spent nuclear fuel generated by these facilities, which are expected to allow NEER to store spent nuclear fuel at these facilities through license expiration.

As owners and operators of nuclear facilities, certain subsidiaries of NEER are subject to the Nuclear Waste Policy Act and are parties to the spent fuel settlement agreement and legal actions described in FPL - FPL Sources of Generation - Nuclear Operations. Similar to FPL, these subsidiaries will continue to pay fees to the U.S. government's nuclear waste fund pending further action by the D.C. Circuit.

Nuclear Regulatory Developments. For discussion of developments regarding the impact of the 2011 earthquake and tsunami in Japan as it relates to U.S. nuclear facilities, see FPL - FPL Sources of Generation - Nuclear Operations. NEER's nuclear facilities are subject to the same NRC actions as described for FPL. Duane Arnold is NEER's only boiling water reactor unit. NEER is currently reviewing the various orders and requests for information being issued by the NRC and assessing the potential financial and operational impact on its nuclear units, which could be significant. NEER's preliminary estimate of the cost to complete the NRC actions established in March 2012 is included in estimated capital expenditures. See Note 13 - Commitments.

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Solar Facilities

NEER is one of the largest owners of utility-scale solar energy projects in North America, principally through a 310 mw facility in California's Mojave Desert, of which 148 mw is owned by NEER as of December 31, 2012. NEER and its affiliates are in the process of constructing solar thermal facilities with generating capacity of 99.8 mw in Spain (Spain solar projects) (see Note 13 - Commitments for recent changes in law that could negatively affect the Spain solar projects) and 250 mw in California (Genesis solar project), which are expected to be completed in 2013 and 2014, respectively. In addition, a 550 mw solar PV project in California (Desert Sunlight solar project), in which NEER has a 50% equity investment, has commenced construction and commercial operation is expected to be phased in during 2013 through 2015. During 2012, NEER acquired 40 mw of new solar generation in Canada.

Other Assets

At December 31, 2012, NEER had 1,155 mw of generation assets from a variety of other fuel technologies, including oil and hydropower, with facilities located throughout the Northeast. In late 2012, a subsidiary of NEER entered into an agreement to sell its ownership interest in a portfolio of hydropower generation plants and related assets with a total generating capacity of 351 mw located in Maine and New Hampshire. Upon the anticipated closing in the first quarter of 2013, NEER will have no further investments in hydropower assets.

Policy Incentives for Renewable Energy Projects

In its development and operation of U.S. wind generation facilities, NEER depends heavily on the federal PTC, which currently provides an income tax credit for the production of electricity from utility-scale wind turbines for the first ten years of commercial operation. This incentive was created under the Energy Policy Act of 1992 and was set to expire such that it would not apply to wind projects that achieve commercial operation after December 31, 2012. Under the American Taxpayer Relief Act of 2012 (Taxpayer Relief Act), the PTC was extended for wind projects whose construction begins by December 31, 2013. Alternatively, wind project developers can choose to receive a 30% ITC, in lieu of the PTC, with the same requirement that construction of the wind project begin by December 31, 2013. For qualifying wind projects where construction began before the end of 2011 and the projects were placed in service in 2012, wind project developers could elect to receive an equivalent cash payment from the U.S. Department of Treasury for the value of the 30% ITC. NEER's expectations for wind development and construction in 2013 and beyond will depend, in part, on rules to be established under the Taxpayer Relief Act.

Solar project developers are also eligible to receive a 30% ITC for new solar projects that achieve commercial operations before 2017. Solar project developers can elect to receive an equivalent cash payment from the U.S. Department of Treasury for the value of the 30% ITC for qualifying solar projects where construction began before the end of 2011 and the projects are placed in service before 2017.

Other countries, including Canada and Spain, provide for incentives like feed-in-tariffs for renewable energy projects. The feed-in-tariffs promote renewable energy investments by offering long-term contracts to renewable energy producers, typically based on the cost of generation of each technology.

NEER Generation by Geographic Region

NEER's generating capacity spans various geographic regions in North America, thereby reducing overall volatility related to varying market conditions and seasonality on a portfolio basis. NEER's generating facilities at December 31, 2012 are categorized by geographic region (see Item 2 - Generating Facilities) in terms of mw of capacity as follows:

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NEER's power generation in terms of mwh produced for the year ended December 31, 2012 by fuel type is as follows:

NEER CUSTOMER SUPPLY AND PROPRIETARY POWER AND GAS TRADING

PMI, a subsidiary of NEER, buys and sells wholesale energy commodities, such as electricity, natural gas and oil. PMI sells the output from NEER's plants that is not sold under long-term contracts and procures the non-nuclear fuel for use by NEER's generation fleet. Its primary role is to manage the commodity risk of NEER's portfolio. 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 NEER's power generation assets.

PMI also provides a wide range of electricity and gas commodity products as well as marketing and trading services to electric and gas utilities, municipalities, cooperatives and other load-serving entities, as well as to owners of electric generation facilities. PMI's customer supply business includes providing full energy and capacity requirements and mid-market services that include sales and purchases of wholesale commodities-related products and the operations of a retail electricity provider, which during 2012, served approximately 2,950 mw of peak load to approximately 209,100 customers across the ERCOT, New England Power Pool (NEPOOL), PJM, NYISO and MISO markets.

The results of PMI's activities are included in NEER's operating results. See Management's Discussion - Energy Marketing and Trading and Market Risk Sensitivity, Note 1 - Energy Trading and Note 3.

NEER REGULATION

The energy markets in which NEER operates are subject to domestic and foreign regulation, including local, state and federal regulation, and other specific rules.

At December 31, 2012, NEER had ownership interests in operating independent power projects located in the U.S. that have received exempt wholesale generator status as defined under the Public Utility Holding Company Act of 2005, which represent approximately 96% of NEER's 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. NEER's exempt wholesale generators produce electricity from wind, hydro, fossil fuels and nuclear facilities. Essentially all of the remaining 4% of NEER's net generating capacity has qualifying facility status under the PURPA. NEER's qualifying facilities generate electricity primarily from wind, solar and fossil fuels. 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, most of the NEER facilities located in the U.S. are subject to FERC regulations and market rules, the NERC's mandatory reliability standards and the EPA's environmental laws, and its nuclear facilities are also subject to the jurisdiction of the NRC. See FPL - FPL Regulation for additional discussion of FERC, NERC, NRC and EPA regulations. With the exception of facilities located in ERCOT, the FERC has jurisdiction over various aspects of NEER's business in the U.S., including the oversight and investigation of competitive wholesale energy markets, regulation of the transmission and sale of natural gas, regulation of hydro projects and oversight of environmental matters related to natural gas and hydro projects and major electricity policy initiatives. The PUCT has jurisdiction, including the regulation of rates and services, oversight of competitive markets, and enforcement of statutes and rules, over NEER facilities located in ERCOT. NEER and its affiliates are also subject to national and provincial or regional regulations in Canada and Spain related to energy operations, energy markets and environmental standards.

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NEER is subject to environmental laws and regulations, and is affected by some of the emerging issues related to renewable energy resources as described in the NEE Environmental Matters section below. In order to better anticipate these potential regulatory changes, NEER continues to actively 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.

NEER EMPLOYEES

NEER and its subsidiaries had approximately 4,700 employees at December 31, 2012. Certain subsidiaries of NEER have collective bargaining agreements with the IBEW, the Utility Workers Union of America, the Security Police and Fire Professionals of America and the International Union of Operating Engineers, which collectively represent approximately 23% of NEER's employees. The collective bargaining agreements have one- to five-year terms and expire between September 2013 and 2015.

III. OTHER NEE OPERATING SUBSIDIARIES

NEE's Corporate and Other segment represents other business activities, primarily NEET and FPL FiberNet, that are not separately reportable. See Note 14.

NEET

NEET, a wholly-owned subsidiary of NEECH, is a limited liability company organized under the laws of Delaware. NEET conducts its business primarily through two subsidiaries, Lone Star and NHT, and is pursuing opportunities to develop, build and operate new transmission facilities throughout North America.

Lone Star

Lone Star is a limited liability company organized under the laws of Delaware. Lone Star, a rate-regulated transmission service provider in Texas, is constructing approximately 330 miles of 345 kilovolt (kv) transmission lines and other associated facilities. Two substations and associated facilities with a total capital investment of approximately $49 million were placed in service in 2012, with the remaining associated facilities and transmission lines expected to be placed in service in March 2013, for a total capital investment of approximately $780 million. Lone Star's transmission lines are part of a transmission grid improvement program that will add approximately 2,300 miles of 345 kv lines to deliver power from the Competitive Renewable Energy Zones in west Texas and the Texas panhandle to the Dallas/Fort Worth area and other population centers in Texas.

Lone Star is subject to regulation by a number of federal, state and other agencies, including, but not limited to, the PUCT, the ERCOT, the NERC and the EPA, as well as certain limited regulations of the FERC. See FPL - FPL Regulation for further discussion of FERC, NERC and EPA regulations and NEE Environmental Matters. The PUCT has jurisdiction over a wide range of Lone Star's business activities, including, among others, rates charged to customers and certain aspects of siting, construction and operation of transmission systems. The PUCT sets rates at a level that allows Lone Star the opportunity to collect from customers total revenues (revenue requirements) equal to Lone Star's cost of providing service, including a reasonable rate of return on invested capital.

In October 2012, the PUCT reached a decision in Lone Star's initial rate case proceeding. In January 2013, the PUCT, during rehearing, approved Lone Star's wholesale transmission service rate reflecting an annual revenue requirement for, among other things, capital investment of approximately $49 million, a regulatory equity ratio of 45%, an allowed regulatory ROE of 9.6% and other operating expenses. The remaining capital investment will be included in Lone Star's rates by means of an interim rate adjustment mechanism. In addition, Lone Star must file a general rate case, with a full 12-month historical test year, within four months of having 12 months of historical operating data, which is expected to occur in mid-2014.

NHT

NHT, a rate-regulated transmission owner in ISO-NE, is a limited liability company organized under the laws of Delaware. NHT owns transmission facilities which connect NEER's Seabrook nuclear facility to the New England transmission grid and interconnect three 345 kv transmission lines in New England. NHT is subject to regulation by a number of federal, state and other agencies, including, but not limited to, the New Hampshire Public Utility Commission, ISO-NE, the FERC, the NERC and the EPA. See FPL - FPL Regulation for further discussion of FERC, NERC and EPA regulations and NEE Environmental Matters. NHT wholesale transmission revenues are provided through an ISO-NE tariff.

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FPL FIBERNET

FPL FiberNet conducts its business through two separate wholly-owned subsidiaries of NEECH. One subsidiary was formed in 2000 to enhance the value of NEE's fiber-optic network assets that were originally built to support FPL operations and the other was formed in 2011 to hold fiber-optic network assets which were acquired. Both subsidiaries are limited liability companies organized under the laws of Delaware. FPL FiberNet leases fiber-optic network capacity and dark fiber to FPL and other customers, primarily telephone, wireless, internet and other telecommunications companies. FPL FiberNet's networks cover most of the metropolitan areas in Florida and several in Texas. FPL FiberNet also has a long-haul network providing bandwidth at wholesale rates. The long-haul network connects major cities in Florida and Texas with additional connectivity to Atlanta, Georgia and the South Central U.S., including Arkansas, Louisiana and Oklahoma. At December 31, 2012, FPL FiberNet's network consisted of approximately 8,600 route miles. FPL FiberNet is subject to regulation by the Federal Communications Commission which has jurisdiction over wire and wireless communication networks and by the public utility commissions in the states in which it provides intrastate telecommunication services.

NEE ENVIRONMENTAL MATTERS

NEE and FPL are subject to domestic and foreign environmental laws and regulations, including extensive federal, state and local environmental statutes, rules and regulations. 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 NEE 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. Based on the most recent reference data available from government sources, NEE is among the lowest emitters, among electric generators, of GHG in the U.S. measured by its rate of emissions expressed as pounds of CO₂ per mwh of generation. However, the legislative and regulatory proposals have differing methods of implementation and the impact on FPL's and NEER's generating units and/or the financial impact (either positive or negative) to NEE and FPL could be material, depending on the eventual structure of any specific implementation rules adopted.

I. Environmental Regulations

The following is a discussion of certain existing and emerging federal and state initiatives and rules, some of which could potentially have a material effect (either positive or negative) on NEE and its subsidiaries. FPL expects to seek recovery through the environmental clause for compliance costs associated with any new environmental laws and regulations.

•

Clean Air Interstate Rule (CAIR)/Cross-State Air Pollution Rule (CSAPR). The EPA's CAIR requires SO₂ and NOx emissions reductions from electric generating units in specified Eastern states and the District of Columbia, where the emissions from electric generating units are deemed to be transported to downwind states. NEER and FPL began complying with the CAIR on January 1, 2009. In July 2011, the EPA issued the CSAPR, a final rule which was to replace the CAIR beginning in January 2012. The CSAPR would limit emissions of SO₂and NOx from power plants in 28 eastern states and provides an allocation methodology for emission allowances and reduction limits for SO₂, NOx and seasonal ozone requirements. In August 2012, the D.C. Circuit vacated the CSAPR and remanded it back to the EPA for further rulemaking. The D.C. Circuit ordered that the CAIR remain in place until such time that the EPA promulgates a valid replacement. Several parties, including the EPA, filed for rehearing, which the D.C. Circuit denied in January 2013. Those parties have until April 2013 to seek review by the U.S. Supreme Court.

•

Clean Water Act Section 316(b). In March 2011, the EPA issued a proposed 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, with a final rule expected by the summer of 2013. The proposed rule is intended to require the Best Technology Available to reduce the impact on aquatic organisms from once-through cooling water intake systems. Under the proposed rule, potentially thirteen of FPL's facilities and five of NEER's facilities may be required to add additional controls and/or make operational changes to comply, 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, states are continuing to utilize "Best Professional Judgment" in the application of Section 316(b) compliance requirements.

•

Regulation of GHG Emissions. The EPA continues to evaluate regulatory options under the Clean Air Act for existing fossil fuel-fired power units. The EPA's proposed rule is anticipated in either late 2013 or early 2014 and could be finalized in late 2014. This EPA guidance will direct each state to develop their respective state implementation plan which will set forth the program requirements within that state, and compliance would be expected over several years.


•	Revisions to the National Ambient Air Quality Standards (NAAQS) for Particulate Matter. In December 2012, the EPA proposed a rule revision for particulate matter NAAQS to lower the annual PM2.5 standard, which proposed rule is not expected to have a significant impact on FPL or NEER facilities.

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•

Avian/Bat Regulations and Wind Turbine Siting Guidelines. NEER and FPL are subject to numerous environmental regulations and guidelines related to threatened and endangered species and their habitats, as well as avian and bat species, for the siting, construction and ongoing operations of their facilities. The facilities most significantly affected are wind facilities and transmission and distribution lines. The environmental laws include, among others, the Endangered Species Act, the Migratory Bird Treaty Act, and the Bald and Golden Eagle Protection Act which provide for protection of migratory birds, eagles and endangered species of birds and bats and their habitats. Regulations have been adopted under some of these laws that contain provisions that allow the owner/operator of a facility to apply for a permit to undertake specific activities including those associated with certain siting decisions, construction activities and operations. In addition to regulations, voluntary wind turbine siting guidelines established by the U.S. Fish and Wildlife Service set forth siting, monitoring and coordination protocols that are designed to support wind development in the U.S. while also protecting both birds and bats and their habitats. These guidelines include provisions for specific monitoring and study conditions which need to be met in order for projects to be in adherence with these voluntary guidelines. Complying with these environmental regulations and adhering to the provisions set forth in the voluntary wind turbine siting guidelines could result in additional costs at existing and new wind generating facilities and transmission and distribution facilities at NEER and FPL.

II. Other GHG Emissions Reduction Initiatives

NEER's plants operate in certain states and regions that continue to consider and implement regulatory proposals to reduce GHG emissions. 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. NEER's plants operate in 19 states that have a RPS and NEER believes that these standards will create incremental demand for renewable energy in the future.

Other GHG reduction initiatives including, among others, the Regional Greenhouse Gas Initiative and the California Greenhouse Gas Regulation aim to reduce emissions through a variety of programs and under varying timelines. Based on its clean generating portfolio, NEER expects to continue experiencing a positive impact on earnings as a result of these GHG reduction initiatives. Additionally, these initiatives provide NEER opportunities with regards to wind and solar development as well as favorable energy pricing.

WEBSITE ACCESS TO SEC FILINGS

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

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EXECUTIVE OFFICERS OF NEE^(a)



Name	Age	Position	Effective Date
Paul I. Cutler	53	Treasurer of NEE Treasurer of FPL Assistant Secretary of NEE	February 19, 2003 February 18, 2003 December 10, 1997
Moray P. Dewhurst	57	Vice Chairman and Chief Financial Officer, and Executive Vice President - Finance of NEE Executive Vice President, Finance and Chief Financial Officer of FPL	October 5, 2011
Shaun J. Francis	41	Executive Vice President, Human Resources and Corporate Services of NEE Executive Vice President, Human Resources and Corporate Services of FPL	January 1, 2013
Chris N. Froggatt	55	Vice President of NEE Controller and Chief Accounting Officer of NEE	October 19, 2009 February 27, 2010
Lewis Hay, III	57	Executive Chairman of NEE	July 1, 2012
Joseph T. Kelliher	52	Executive Vice President, Federal Regulatory Affairs of NEE	May 18, 2009
Manoochehr K. Nazar	58	Executive Vice President, Nuclear Division and Chief Nuclear Officer of NEE Executive Vice President, Nuclear Division and Chief Nuclear Officer of FPL	January 1, 2010 January 15, 2010
Armando Pimentel, Jr.	50	President and Chief Executive Officer of NEER	October 5, 2011
James L. Robo	50	President and Chief Executive Officer of NEE Chairman and Chief Executive Officer of FPL	July 1, 2012 May 2, 2012
Antonio Rodriguez^(b)	70	Executive Vice President, Power Generation Division of NEE Executive Vice President, Power Generation Division of FPL	January 1, 2007 July 1, 1999
Charles E. Sieving	40	Executive Vice President & General Counsel of NEE Executive Vice President of FPL	December 1, 2008 January 1, 2009
Eric E. Silagy	47	President of FPL	December 16, 2011
William L. Yeager	54	Executive Vice President, Engineering, Construction & Integrated Supply Chain of NEE Executive Vice President, Engineering, Construction & Integrated Supply Chain of FPL	January 1, 2013

______________________

(a)

Information is as of February 27, 2013. 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. Dewhurst has been vice chairman of NEE since August 2009 and was chief of staff of NEE from August 2009 to October 2011. From July 2001 to May 2008, Mr. Dewhurst was vice president, finance and chief financial officer of NEE and senior vice president, finance and chief financial officer of FPL. Mr. Francis has been executive vice president of human resources of NEE since August 2010 and executive vice president of human resources of FPL since January 2011. Mr. Francis was general manager of human resources for a division of General Electric Company, GE Transportation, a supplier to the railroad, marine, drilling, mining and wind power industries from February 2008 to August 2010. 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 electric utility, from December 2008 to October 2009. From October 2002 to December 2008, Mr. Froggatt was vice president, controller and chief accounting officer of APS. Mr. Hay was chief executive officer of NEE from June 2001 to June 2012. Mr. Hay was also chairman of NEE from January 2002 to June 2012 and chairman of FPL from January 2002 to May 2012. From January 2002 to July 2008, Mr. Hay was also chief executive officer of FPL. Mr. Kelliher was chairman of the FERC from July 2005 to January 2009. Mr. Nazar was the chief nuclear officer of NEE from January 2009 to December 2009. From January 2009 to January 2010, Mr. Nazar was the senior vice president and chief nuclear officer of FPL. Mr. Nazar was senior vice president and nuclear chief operating officer of FPL from November 2007 to January 2009. Mr. Pimentel was chief financial officer of NEE and FPL from May 2008 to October 2011 and executive vice president, finance of NEE and FPL from February 2008 to October 2011. Mr. Robo was president and chief operating officer of NEE from December 2006 to June 2012. Mr. Sieving was also assistant secretary of NEE from May 2010 to May 2011 and 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. Mr. Silagy was senior vice president, regulatory and state governmental affairs of FPL from May 2010 to December 2011. Mr. Silagy was vice president and chief development officer of FPL from July 2008 to May 2010. From November 2007 to July 2008, Mr. Silagy was vice president, development of FPL. Mr. Yeager was vice president, engineering, construction and integrated supply chain services of NEE and FPL from October 2012 to December 2012. Mr. Yeager was vice president, integrated supply chain of NEE and FPL from May 2011 to October 2012. From January 2005 to May 2011, Mr. Yeager was vice president, engineering and construction of FPL.


(b)	NEE title changed from vice president to executive vice president effective May 23, 2008 and 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 NEE's and FPL's Business

The business, financial condition, results of operations and prospects of NEE and FPL are subject to a variety of risks, many of which are beyond the control of NEE and FPL. The following is a description of important risks that may adversely affect the business, financial condition, results of operations and prospects of NEE and FPL and may cause actual results of NEE and FPL to differ substantially from those that NEE or FPL currently expects or seeks. In that event, the market price for the securities of NEE or FPL could decline. Accordingly, the risks described below should be carefully considered together with the other information set forth in this report and in future reports that NEE and FPL file with the SEC. The risks described below are not the only risks facing NEE and FPL. Additional risks and uncertainties may also materially adversely affect NEE's or FPL's business, financial condition, results of operations and prospects. Each of NEE and FPL has disclosed the material risks known to it to affect its business at this time. However, there may be further risks and uncertainties that are not presently known or that are not currently believed to be material that may in the future adversely affect the performance or financial condition of NEE and FPL.

Regulatory, Legislative and Legal Risks

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

The operations of NEE and FPL are subject to complex and comprehensive federal, state and other regulation. This extensive regulatory framework, portions of which are more specifically identified in the following risk factors, regulates, among other things and to varying degrees, NEE's and FPL's industries, rates and cost structures, operation of nuclear power facilities, construction and operation of generation, transmission and distribution facilities and natural gas and oil production, transmission and fuel storage facilities, acquisition, disposal, depreciation and amortization of facilities and other assets, decommissioning costs and funding, service reliability, wholesale and retail competition, and commodities trading and derivatives transactions. In their business planning and in the management of their operations, NEE and FPL must address the effects of regulation on their business and any inability or failure to do so adequately could have a material adverse effect on their business, financial condition, results of operations and prospects.

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

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 through base rates and cost recovery clauses, the terms and conditions of its services, procurement of electricity for its customers, issuance of securities, and aspects of the siting and operation of its generating plants and transmission and distribution systems for the sale of electric energy. The FPSC has the authority to disallow recovery by FPL of costs that it considers excessive or imprudently incurred and to determine the level of return that FPL is permitted to earn on its investments. The regulatory process, which may be adversely affected by the political, regulatory and economic environment in Florida and elsewhere, limits FPL's ability to increase earnings and does not provide any assurance as to achievement of authorized or other earnings levels. NEE's and FPL's business, financial condition, results of operations and prospects 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, other regulatory mechanisms or otherwise. Lone Star, an indirect wholly-owned subsidiary of NEE that is a regulated electric transmission utility subject to the jurisdiction of the PUCT, is subject to similar risks.

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

The local and national political, regulatory and economic environment has had, and may in the future have, an adverse effect on FPSC decisions with negative consequences for FPL. These decisions may require, for example, FPL to cancel or delay planned development activities, to reduce or delay other planned capital expenditures or to pay for investments or otherwise incur costs that it may not be able to recover through rates, each of which could have a material adverse effect on the business, financial condition, results of operations and prospects of NEE and FPL. Lone Star is subject to similar risks.

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

In the event that the FPSC engages in a prudence review of FPL's use of derivative instruments and finds such use to be imprudent, the FPSC could deny cost recovery for such use by FPL. Such an outcome could have a material adverse effect on FPL's business, financial condition, results of operations and prospects.

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

NEER depends heavily on government policies that support renewable energy and enhance the economic feasibility of developing and operating wind and solar energy projects in regions in which NEER operates or plans to develop and operate renewable energy facilities. 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 energy facilities, such as wind and solar energy facilities. As a result of budgetary constraints, political factors or otherwise, governments from time to time may review their policies that support renewable energy and consider actions to make the policies less conducive to the development and operation of renewable energy facilities. Any reductions to, or the elimination of, governmental incentives that support renewable energy, such as those reductions that have been enacted in Spain and are applicable to the Spain solar projects in that country, or the imposition of additional taxes or other assessments on renewable energy, could result in, among other items, the lack of a satisfactory market for the development of new renewable energy projects, NEER abandoning the development of renewable energy projects, a loss of NEER's investments in the projects and reduced project returns, any of which could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.

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

NEE's and FPL's business is influenced by various legislative and regulatory initiatives, including, but not limited to, initiatives regarding deregulation or restructuring of the energy industry, regulation of the commodities trading and derivatives markets, and environmental regulation, such as regulation of air emissions, regulation of water consumption and water discharges, and regulation of gas and oil infrastructure operations, as well as associated environmental permitting. Changes in the nature of the regulation of NEE's and FPL's business could have a material adverse effect on NEE's and FPL's results of operations. NEE and FPL are unable to predict future legislative or regulatory changes, initiatives or interpretations, although any such changes, initiatives or interpretations may increase costs and competitive pressures on NEE and FPL, which could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

FPL has limited competition in the Florida market for retail electricity customers. Any changes in Florida law or regulation which introduce competition in the Florida retail electricity market could have a material adverse effect on FPL's business, financial condition, results of operations and prospects. There can be no assurance that FPL will be able to respond adequately to such regulatory changes, which could have a material adverse effect on FPL's business, financial condition, results of operations and prospects.

NEER is subject to FERC rules related to transmission that are designed to facilitate competition in the wholesale market on practically a nationwide basis by providing greater certainty, flexibility and more choices to wholesale power customers. NEE cannot predict the impact of changing FERC rules or the effect of changes in levels of wholesale supply and demand, which are typically driven by factors beyond NEE's control. There can be no assurance that NEER will be able to respond adequately or sufficiently quickly to such rules and developments, or to any other changes that reverse or restrict the competitive restructuring of the energy industry in those jurisdictions in which such restructuring has occurred. Any of these events could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.

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

The Dodd-Frank Act, enacted into law in July 2010, among other things, provides for the regulation of the OTC derivatives market. The Dodd-Frank Act includes provisions that will require certain OTC derivatives, or swaps, to be centrally cleared and executed through an exchange or other approved trading platform. While the legislation is broad and detailed, there are still substantial portions of the legislation that either require implementing rules to be adopted by federal governmental agencies including, but not limited to, the SEC and the CFTC or otherwise require further interpretation guidance from federal government agencies.

NEE and FPL cannot predict the final rules that will be adopted to implement the OTC derivatives market provisions of the Dodd-Frank Act (or the ultimate interpretation of those rules). Those rules could negatively affect NEE's and FPL's ability to hedge their commodity and interest rate risks, which could have a material adverse effect on NEE's and FPL's results of operations. NEE is reviewing the scope of these rules and is evaluating whether it may have portions of its business that may be required to register as swap dealers or major swap participants and submit to extensive regulation if it wishes to continue certain aspects of its derivative activities. The rules could also cause NEER to restructure part of its energy marketing and trading operations or to discontinue certain portions of its business. In addition, if the rules require NEE and FPL to post significant amounts of cash collateral with respect to swap transactions, NEE's and FPL's liquidity could be materially 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

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the rules also could significantly increase operating costs and expose NEE and FPL to penalties for non-compliance. The Dodd-Frank Act or other initiatives also could impede the efficient operation of the commodities trading and derivatives markets, which could also materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.

NEE and FPL are subject to numerous environmental laws, regulations and other standards that may result in capital expenditures, increased operating costs and various liabilities.

NEE 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, emissions of greenhouse gases, including, but not limited to, CO₂, waste management, hazardous wastes, marine, avian and other wildlife mortality and habitat protection, historical artifact preservation, natural resources, health (including, but not limited to, electric and magnetic fields from power lines and substations), 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, increase capital expenditures and limit or eliminate certain 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, the use of hydraulic fracturing or similar technologies to drill for natural gas and related compounds used by NEE's gas infrastructure business is currently being debated for potential regulation at the state and federal levels.

Violations of current or future laws, rules, regulations or other standards could expose NEE and FPL to regulatory and legal proceedings, disputes with, and legal challenges by, third parties, and potentially significant civil fines, criminal penalties and other sanctions. Proceedings could include, for example, litigation regarding property damage, personal injury, common law nuisance and enforcement by citizens or governmental authorities of environmental requirements such as air, water and soil quality standards.

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

Federal or state laws or regulations may be adopted that would impose new or additional limits on the emissions of greenhouse gases, including, but not limited to, CO2 and methane, from electric generating units using fossil fuels like coal and natural gas. The potential effects of such greenhouse gas emission limits on NEE'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 greenhouse gas emission reduction offsets, the development of cost-effective, commercial-scale carbon capture and storage technology and supporting regulations and liability mitigation measures, and the range of available compliance alternatives.

While NEE's and FPL's electric generating units emit greenhouse gases at a lower rate of emissions than most of the U.S. electric generation sector, the results of operations of NEE and FPL could be adversely affected to the extent that new federal or state legislation or regulators impose any new greenhouse gas emission limits. Any future limits on greenhouse gas emissions could:


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


•	make some of NEE'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


•	affect the availability or cost of fossil fuels.

There can be no assurance that NEE or FPL would be able to completely recover any such costs or investments, which could have a material adverse effect on their business, financial condition, results of operations and prospects.

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

NEE and FPL are subject to extensive federal regulation, which generally imposes significant and increasing compliance costs on NEE's and FPL's operations. Additionally, any actual or alleged compliance failures could result in significant costs and other potentially adverse effects of regulatory investigations, proceedings, settlements, decisions and claims, including, among other items, potentially significant monetary penalties. As an example, under the Energy Policy Act of 2005, NEE 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 NEE and FPL to higher operating costs and may result in increased capital expenditures. If FPL or NEE is found not to be in compliance with these standards, it may incur substantial monetary penalties and other sanctions. Both the costs of regulatory compliance and the costs that may be imposed as a result of any actual or alleged compliance failures could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

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

NEE's and FPL's provision for income taxes and reporting of tax-related assets and liabilities require 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, the financial condition and results of operations of NEE and FPL, and the resolution of audit issues raised by taxing authorities. Ultimate resolution of income tax matters may result in material adjustments to tax-related assets and liabilities, which could negatively affect NEE's and FPL's business, financial condition, results of operations and prospects.

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

NEE's and FPL's business, financial condition, results of operations and prospects may be materially affected by adverse results of litigation. Unfavorable resolution of legal proceedings in which NEE is involved or other future legal proceedings, including, but not limited to, class action lawsuits, may have a material adverse effect on the business, financial condition, results of operations and prospects of NEE and FPL.

Operational Risks

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

NEE's and FPL's ability to complete construction of, and capital improvement projects for, their electric generation, transmission and distribution facilities, gas infrastructure facilities 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 or on schedule, disputes involving contractors, labor organizations, land owners, governmental entities, environmental groups, Native American and aboriginal groups, and other third parties, negative publicity, transmission interconnection issues and other factors. If any development project or construction or capital improvement project is not completed, is delayed or is subject to cost overruns, certain associated costs may not be approved for recovery or recoverable through regulatory mechanisms that may otherwise be available, and NEE and FPL could become obligated to make delay or termination payments or become obligated for other damages under contracts, could experience the loss of tax credits or tax incentives, or delayed or diminished returns and could be required to write-off all or a portion of their investment in the project. Any of these events could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

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

NEE and FPL own, develop, construct, manage and operate electric-generating and transmission facilities. A key component of NEE's and FPL's growth is their ability to construct and operate generation and transmission facilities to meet customer needs. As part of these operations, NEE 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 NEE 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 associated investigations or enforcement actions or impose related penalties or disallowances on NEE or FPL, NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected. Any failure to negotiate successful project development agreements for new facilities with third parties could have similar results.

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

NEE's and FPL's electric generation, transmission and distribution facilities, gas infrastructure facilities and other facilities are subject to many operational risks. Operational risks could result in, among other things, lost revenues due to prolonged outages, increased expenses due to monetary penalties or fines for compliance failures, liability to third parties for property and personal injury damage, a failure to perform under applicable power sales agreements and associated loss of revenues from terminated agreements or liability for liquidated damages under continuing agreements, and replacement equipment costs or an obligation to purchase or generate replacement power at potentially higher prices.

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Uncertainties and risks inherent in operating and maintaining NEE's and FPL's facilities include, but are not limited to:


•	risks associated with facility start-up operations, such as whether the facility will achieve projected operating performance on schedule and otherwise as planned;


•	failures in the availability, acquisition or transportation of fuel or other necessary supplies;


•	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, including, but not limited to, explosions, fires or other major events, of equipment, transmission and distribution lines or pipelines;


•	availability of replacement equipment;


•	risks of property damage or human injury from energized equipment, hazardous substances or explosions, fires or other events;


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


•	inability to manage properly or mitigate known equipment defects in NEE's and FPL's facilities;


•	use of new or unproven technology;


•	risks associated with dependence on a specific fuel source, such as commodity price risk and lack of available alternative fuel sources;


•	increased competition due to, among other factors, new facilities, excess supply and shifting demand; and


•	insufficient insurance, warranties or performance guarantees to cover any or all lost revenues or increased expenses from the foregoing.

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

Growth in customer accounts and growth of customer usage each directly influence the demand for electricity and the need for additional power generation and power delivery facilities. Customer growth and customer usage are affected by a number of factors outside the control of NEE and FPL, such as mandated energy efficiency measures, demand side management goals, and economic and demographic conditions, such as population changes, job and income growth, housing starts, new business formation and the overall level of economic activity. A lack of growth, or a decline, in the number of customers or in customer demand for electricity may cause NEE and FPL to fail to fully realize the anticipated benefits from significant investments and expenditures and could have a material adverse effect on NEE's and FPL's own growth, business, financial condition, results of operations and prospects.

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

Weather conditions directly influence the demand for electricity and natural gas and other fuels and affect the price of energy and energy-related commodities. In addition, severe weather, such as hurricanes, floods and earthquakes, can be destructive and cause power outages and property damage, reduce revenue, affect fuel supply, and require NEE and FPL to incur additional costs, for example, to restore service and repair damaged facilities, obtain replacement power and access available financing sources. Furthermore, NEE's and FPL's physical plant could be placed at greater risk of damage should changes in global climate produce unusual variations in temperature and weather patterns, resulting in more intense, frequent and extreme weather events, abnormal levels of precipitation and, particularly relevant to FPL, a change in sea level. FPL operates in the east and lower west coasts of Florida, an area that historically has been 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 NEE and FPL from operating their business in the normal course and could result in any of the adverse consequences described above. Any of the foregoing could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

At FPL and other businesses of NEE where cost recovery is available, 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 could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

Changes in weather can also affect the production of electricity at power generating facilities, including, but not limited to, NEER's wind, solar and hydro-powered facilities. For example, the level of wind resource affects the revenue produced by wind generating facilities. Because the levels of wind, solar and hydro resources are variable and difficult to predict, NEER's results of operations for individual wind, solar and hydro facilities specifically, and NEE's results of operations generally, 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 financial results from these facilities may be less than expected.

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

NEE 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. NEE's and FPL's generation, transmission and distribution facilities, fuel storage facilities, information technology systems and other infrastructure facilities and systems could be direct targets of, or be indirectly affected by, such activities.

Terrorist acts or other similar events affecting NEE's and FPL's systems and facilities, or those of third parties on which NEE and FPL rely, could harm NEE's and FPL's business, for example, by limiting their ability to generate, purchase or transmit power, by limiting their ability to bill customers and collect and process payments, and by delaying their development and construction of new generating facilities or capital improvements to existing facilities. These events, and governmental actions in response, could result in a material decrease in revenues, significant additional costs (for example, to repair assets, implement additional security requirements or maintain or acquire insurance), and reputational damage, could adversely affect NEE's and FPL's operations (for example, by contributing to disruption of supplies and markets for natural gas, oil and other fuels), and could impair NEE's and FPL's ability to raise capital (for example, by contributing to financial instability and lower economic activity).

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

Insurance coverage may not continue to be available or may not be available at rates or on terms similar to those presently available to NEE and FPL. The ability of NEE and FPL to obtain insurance and the terms of any available insurance coverage could be adversely affected by international, national, state or local events and company-specific events, as well as the financial condition of insurers. If insurance coverage is not available or obtainable on acceptable terms, NEE or FPL may be required to pay costs associated with adverse future events. NEE and FPL generally are not fully insured against all significant losses. For example, FPL is not fully insured against hurricane-related losses, but would instead seek recovery of such uninsured losses from customers subject to approval by the FPSC, to the extent losses exceed restricted funds set aside to cover the cost of storm damage. A loss for which NEE or FPL is not fully insured could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

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

NEER provides full energy and capacity requirements services primarily to distribution utilities, which include load-following services and various ancillary services 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 such utilities have 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. NEER may not be able to recover all of its increased supply costs, which could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.

Due to the potential for significant volatility in market prices for fuel, electricity and renewable and other energy commodities, NEER's inability or failure to hedge effectively its assets or positions against changes in commodity prices, volumes, interest rates, counterparty credit risk or other risk measures could significantly impair NEE's results of operations.

There can be significant volatility in market prices for fuel, electricity and renewable and other energy commodities. NEE's inability to manage properly or hedge the commodity risks within its portfolios, based on factors both from within or wholly or partially outside of NEE's control, may materially adversely affect NEE's business, financial condition, results of operations and prospects.

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

A portion of NEER's power generation facilities operate wholly or partially without long-term power purchase agreements. Power from these facilities is sold on the spot market or on a short-term contractual basis. Spot market sales are subject to market volatility, and the revenue generated from these sales is subject to fluctuation that may cause NEE's results of operations to be volatile. NEER and NEE may not be able to manage volatility adequately, which could then have a material adverse effect on NEE's business, financial condition, results of operations and prospects.

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

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NEE 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, and any reduction in the liquidity of energy markets could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.

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

NEE 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. NEE and FPL are unable to assure that such procedures and tools will be effective against all potential risks. Additionally, 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. Due to the inherent uncertainty involved in price movements and potential deviation from historical pricing behavior, NEE and FPL are unable to assure that their risk management tools and metrics will be effective to protect against adverse effects on their business, financial condition, results of operations and prospects. Such adverse effects could be material.

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

FPL and NEER depend upon power transmission and natural gas, nuclear fuel and other commodity transportation facilities, many of which they do not own. Occurrences affecting the operation of these facilities that may or may not be beyond FPL's and NEER's control (such as severe weather or a generator or transmission facility outage, pipeline rupture, or sudden and significant increase or decrease in wind generation) may limit or halt the ability of FPL and NEER to sell and deliver power and natural gas, or to purchase necessary fuels and other commodities, which could materially adversely impact NEE's and FPL's business, financial condition, results of operations and prospects.

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

NEE 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, hedging counterparties and vendors, may affect the ability of some customers, hedging counterparties and vendors to perform as required under their contracts with NEE and FPL.

If any hedging, vending or other counterparty fails to fulfill its contractual obligations, NEE and FPL may need to make arrangements with other counterparties or vendors, which could result in financial losses, higher costs, untimely completion of power generation facilities and other projects, and/or a disruption of their operations. If a defaulting counterparty is in poor financial condition, NEE and FPL may not be able to recover damages for any contract breach.

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

NEE and FPL use derivative instruments, such as swaps, options, futures and forwards, some of which are traded in the OTC markets or on exchanges, to manage their commodity and financial market risks, and for NEE to engage in trading and marketing activities. Any failures by their counterparties to perform or make payments in accordance with the terms of those transactions could have a material adverse effect on NEE's or FPL's business, financial condition, results of operations and prospects. Similarly, any requirement for FPL or NEE to post margin cash collateral under its derivative contracts could have a material adverse effect on its business, financial condition, results of operations and prospects.

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

NEE and FPL operate in a highly regulated industry that requires the continuous functioning of sophisticated information technology systems and network infrastructure. Despite NEE'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 NEE's or FPL's information technology systems were to fail or be breached, and NEE or FPL was unable to recover in a timely way, NEE and FPL would be unable to fulfill critical business functions, and sensitive confidential and other data could be compromised.

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NEE's and FPL's business is 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 NEE's and FPL's business, and due to the complexity of the process of power generation, transmission and distribution, the development and maintenance of information technology systems to keep track of and process this information is both critical and extremely challenging. NEE'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 affect NEE's and FPL's ability to process transactions and provide services, and their financial results and liquidity.

NEE 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 companies' ability to timely file required regulatory reports.

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

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

NEE's and FPL's retail businesses require access to sensitive customer data in the ordinary course of business. NEE's and FPL's retail 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 NEE and FPL could be adversely affected, customer confidence could be diminished, or customer information could be subject to identity theft. NEE and FPL would be subject to costs associated with the breach and/or NEE and FPL could be subject to fines and legal claims, any of which may have a material adverse effect on the business, financial condition, results of operations and prospects of NEE and FPL.

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

NEE and FPL execute transactions in derivative instruments on either recognized exchanges or via the OTC markets, depending on management's assessment of the most favorable credit and market execution factors. Transactions executed in OTC markets have the potential for greater volatility and less liquidity than transactions on recognized exchanges. As a result, NEE and FPL may not be able to execute desired OTC transactions due to such heightened volatility and limited liquidity.

In the absence of actively quoted market prices and pricing information from external sources, the valuation of derivative instruments involves management's judgment or use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these derivative instruments and have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

NEE and FPL may be adversely affected by 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 NEE and FPL. Adverse press coverage and other adverse statements, whether or not driven by political or public sentiment, may also result in investigations by regulators, legislators and law enforcement officials or in legal claims. Responding to these investigations and lawsuits, regardless of the ultimate outcome of the proceeding, can divert the time and effort of senior management from NEE's and FPL's business.

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 have a negative impact on the reputation of NEE and FPL, on the morale and performance of their employees and on their relationships with their respective regulators. It may also have a negative impact on their ability to take timely advantage of various business and market opportunities. The direct and indirect effects of negative publicity, and the demands of responding to and addressing it, may have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

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

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FPL must negotiate franchise agreements with municipalities and counties in Florida to provide electric services within such municipalities and counties, and electricity sales generated pursuant to these agreements represent a very substantial portion of FPL's revenues. If FPL is unable to maintain, negotiate or renegotiate such franchise agreements on acceptable terms, it could contribute to lower earnings and FPL may not fully realize the anticipated benefits from significant investments and expenditures, which could materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.

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

The costs of providing health care benefits to employees and retirees have increased substantially in recent years. NEE and FPL anticipate 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 NEE's and FPL's health care plans may materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.

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

NEE and FPL may not be able to service customers, grow their business or generally meet their other business plan goals effectively and profitably if they do not attract and retain a qualified workforce. Additionally, the loss or retirement of key executives and other employees may materially adversely affect service and productivity and contribute to higher training and safety costs.

Over the next several years, a significant portion of NEE'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. If a significant amount of such workers retire and are not replaced, the subsequent loss in productivity and increased recruiting and training costs could result in a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

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

Employee strikes or work stoppages could disrupt operations and lead to a loss of revenue and customers. Personnel costs may also increase due to inflationary or competitive pressures on payroll and benefits costs and revised terms of collective bargaining agreements with union employees. These consequences could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

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

NEE 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, NEE may be unable to identify attractive acquisition opportunities at favorable prices and to complete and integrate them successfully and in a timely manner.

Nuclear Generation Risks

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

NEE's and FPL's nuclear generation facilities are subject to environmental, health and financial risks, including, but not limited to, those 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. NEE and FPL maintain decommissioning funds and external insurance coverage which are intended to reduce the financial exposure to some of these risks; however, the cost of decommissioning nuclear generation facilities could exceed the amount available in NEE's and FPL's decommissioning funds, and the exposure to liability and property damages could exceed the amount of insurance coverage. If NEE or FPL is unable to recover the additional costs incurred through insurance or, in the case of FPL, through regulatory mechanisms, their business, financial condition, results of operations and prospects could be materially adversely affected.

In the event of an incident at any nuclear generation facility in the U.S. or at certain nuclear generation facilities in Europe, NEE and FPL could be assessed significant retrospective assessments and/or retrospective insurance premiums as a result of their participation in a secondary financial protection system and nuclear insurance mutual companies.

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Liability for accidents at nuclear power plants is governed by the Price-Anderson Act, which limits the liability of nuclear reactor owners to the amount of insurance available from both private sources and an industry retrospective payment plan. In accordance with this Act, NEE maintains $375 million of private liability insurance per site, which is the maximum obtainable, and participates in a secondary financial protection system, which provides up to $12.2 billion of liability insurance coverage per incident at any nuclear reactor in the U.S. Under the secondary financial protection system, NEE is subject to retrospective assessments and/or retrospective insurance premiums of up to $940 million ($470 million for FPL), plus any applicable taxes, per incident at any nuclear reactor in the U.S. or at certain nuclear generation facilities in Europe, regardless of fault or proximity to the incident, payable at a rate not to exceed $140 million ($70 million for FPL) per incident per year. Such assessments, if levied, could materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects.

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

The NRC has broad authority to impose licensing and safety-related requirements for the operation and maintenance of nuclear generation facilities, the addition of capacity at existing nuclear generation facilities and the construction of nuclear generation facilities, and these 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. Any of the foregoing events could require NEE and FPL to incur increased costs and capital expenditures, and could reduce revenues.

Any serious nuclear incident occurring at a NEE 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, reduce revenues and result in additional capital expenditures.

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

The operating licenses for NEE's and FPL's nuclear generation facilities extend through at least 2030. If the facilities cannot be operated for any reason through the life of those operating licenses, NEE or FPL may be required to increase depreciation rates, incur impairment charges and accelerate future decommissioning expenditures, any of which could materially adversely affect their business, financial condition, results of operations and prospects.

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

The threat of terrorist activity, as well as recent international events implicating the safety of nuclear facilities, could result in more stringent or complex measures to keep facilities safe from a variety of hazards, including, but not limited to, natural disasters such as earthquakes and tsunamis, as well as terrorist or other criminal threats. This increased focus on safety could result in higher compliance costs which, at present, cannot be assessed with any measure of certainty and which could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

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

NEE's and FPL's nuclear units are periodically removed from service to accommodate normal refueling and maintenance outages, including, but not limited to, inspections, repairs and certain other modifications. In addition, outages may be scheduled, often in connection with a refueling outage, to replace equipment, to increase the generation capacity at a particular nuclear unit, or for other purposes, and those planned activities increase the time the unit is not in operation. In the event that a scheduled outage lasts longer than anticipated or in the event of an unplanned outage due to, for example, equipment failure, such outages could materially adversely affect NEE's or FPL's business, financial condition, results of operations and prospects.

Liquidity, Capital Requirements and Common Stock Risks

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

Table of Contents

NEE 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, including, but not limited to, the conditions of the most recent financial crises in the U.S. and abroad, could increase NEE's and FPL's cost of capital. If NEE 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 business, could contribute to lower earnings and reduced financial flexibility, and could have a material adverse effect on its business, financial condition, results of operations and prospects.

Although NEE's competitive energy subsidiaries have used non-recourse or limited-recourse, project-specific financing in the past, market conditions and other factors could adversely affect the future availability of such financing. The inability of NEE'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 NEE and/or NEECH 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. Such an occurrence also could result in NEE expending additional funds or incurring additional obligations over the shorter term to ensure continuing compliance with project-specific financing arrangements based upon the expectation of improvement in the project's performance or financial returns over the longer term. Any of these actions could materially adversely affect NEE's business, financial condition, results of operations and prospects, as well as the availability or terms of future financings for NEE or its subsidiaries.

NEE's, NEECH's and FPL's inability to maintain their current credit ratings may adversely affect NEE's and FPL's liquidity and results of operations, limit the ability of NEE and FPL to grow their business, and increase interest costs.

The inability of NEE, NEECH 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 NEE's and FPL's ability to grow their business 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 NEE, NEECH and FPL will not be lowered or withdrawn entirely by a rating agency.

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

The inability of NEE's, NEECH's and FPL's credit providers to fund their credit commitments or to maintain their current credit ratings could require NEE, NEECH 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 and could have a material adverse effect on NEE's and FPL's liquidity.

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

NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries. A decline in the market value of the assets held in the defined benefit pension plan due to poor investment performance or other factors may increase the funding requirements for this obligation.

NEE'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 a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

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

NEE and FPL are required to maintain decommissioning funds to satisfy their future obligations to decommission their nuclear power plants. A decline in the market value of the assets held in the decommissioning funds due to poor investment performance or other factors may increase the funding requirements for these obligations. Any increase in funding requirements may have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.

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

Table of Contents

NEE holds other investments where changes in the fair value affect NEE's financial results. In some cases there may be no observable market values for these investments, requiring fair value estimates to be based on other valuation techniques. This type of analysis requires significant judgment and the actual values realized in a sale of these investments could differ materially from those estimated. A sale of an investment below previously estimated value, or other decline in the fair value of an investment, could result in losses or the write-off of such investment, and may have a material adverse effect on NEE's financial condition and results of operations.

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

NEE is a holding company and, as such, has no material operations of its own. Substantially all of NEE's consolidated assets are held by its subsidiaries. NEE'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 its 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 NEE.

NEE's subsidiaries are separate legal entities and have no independent obligation to provide NEE with funds for its payment obligations. The subsidiaries have financial obligations, including, but not limited to, payment of debt service, which they must satisfy before they can fund NEE. In addition, in the event of a subsidiary's liquidation or reorganization, NEE's right to participate in a distribution of assets is subject to the prior claims of the subsidiary's creditors.

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 NEE's subsidiaries to pay upstream dividends or to repay funds.

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

NEE guarantees many of the obligations of its consolidated subsidiaries, other than FPL, through guarantee agreements with NEECH. These guarantees may require NEE to provide substantial funds to its subsidiaries or their creditors or counterparties at a time when NEE is in need of liquidity to meet its own financial obligations. Funding such guarantees may materially adversely affect NEE's ability to pay dividends.

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

The market price and trading volume of NEE's common stock are subject to fluctuations as a result of, among other factors, general credit and capital market conditions and changes in market sentiment regarding the operations, business and financing strategies of NEE and its subsidiaries. As a result, disruptions, uncertainty or volatility in the credit and capital markets may, for example, have a material adverse effect on the market price of NEE's common stock.

Item 1B. Unresolved Staff Comments

None

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Item 2. Properties

NEE and its subsidiaries maintain properties which are adequate for their operations. The principal properties of FPL and NEER are described below.

Generating Facilities

FPL

At December 31, 2012, the electric generating, transmission, distribution and general facilities of FPL represented approximately 50%, 11%, 34% and 5%, respectively, of FPL's gross investment in electric utility plant in service and other property. At December 31, 2012, FPL had the following generating facilities:



FPL Facilities	Location	No. of Units	Fuel	Net Capability (mw)^(a)
Fossil
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	1,141	^(b)
Martin	Indiantown, FL	2	Gas	938
Putnam	Palatka, FL	2	Gas/Oil	498
Sanford	Lake Monroe, FL	2	Gas	1,946
Turkey Point	Florida City, FL	1	Gas/Oil	1,148
West County	West Palm Beach, FL	3	Gas/Oil	3,657

Steam turbines
Manatee	Parrish, FL	2	Oil/Gas	1,621
Martin	Indiantown, FL	2	Oil/Gas	1,652
Port Everglades	Port Everglades, FL	2	Oil/Gas	761	^(c)
St. Johns River Power Park	Jacksonville, FL	2	Coal/Petroleum Coke	254	^(d)
Scherer	Monroe County, GA	1	Coal	642	^(e)
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

Nuclear
St. Lucie	Hutchinson Island, FL	2	Nuclear	1,824	^(f)
Turkey Point	Florida City, FL	2	Nuclear	1,502

Solar PV
DeSoto	Arcadia, FL	1	Solar PV	25
Space Coast	Cocoa, FL	1	Solar PV	10
TOTAL				24,057	^(g)

______________________


(a)	Represents FPL's net ownership interest in warm weather peaking capability.


(b)	The megawatts generated by the 75 mw solar thermal facility replace steam produced by this unit and therefore are not incremental.


(c)	As part of the modernization of the Port Everglades plant, two units were retired in November 2012 and the remaining two units will be retired during the first quarter of 2013.


(d)	Represents FPL's 20% ownership interest in each of SJRPP Units Nos. 1 and 2, which are jointly owned with JEA.


(e)	Represents FPL's approximately 76% ownership of Scherer Unit No. 4, which is jointly owned with JEA.


(f)	Excludes Orlando Utilities Commission's and the Florida Municipal Power Agency's combined share of approximately 15% of St. Lucie Unit No. 2.


(g)	Substantially all of FPL's properties are subject to the lien of FPL's mortgage.

Table of Contents

NEER

At December 31, 2012, NEER had the following generating facilities:

NEER Facilities

Location

Geographic

Region

No.

of Units

Fuel

Net

Capability

(mw)^(a)

Wind

Ashtabula Wind^(b)(c)

Barnes County, ND

Midwest

Wind

148

Ashtabula Wind II^(b)(c)

Griggs & Steele Counties, ND

Midwest

Wind

120

Ashtabula Wind III

Barnes County, ND

Midwest

Wind

Baldwin Wind^(b)

Burleigh County, ND

Midwest

Wind

102

Blackwell Wind

Kay County, OK

Other South

Wind

Blue Summit

Wilbarger County, TX

Texas

Wind

135

Buffalo Ridge

Lincoln County, MN

Midwest

Wind

Butler Ridge Wind^(b)(c)

Dodge County, WI

Midwest

Wind

Cabazon^(b)

Riverside County, CA

West

Wind

Callahan Divide^(b)

Taylor County, TX

Texas

Wind

114

Capricorn Ridge^(c)

Sterling & Coke Counties, TX

Texas

208

Wind

364

Capricorn Ridge Expansion^(c)

Sterling & Coke Counties, TX

Texas

199

Wind

298

Cerro Gordo^(b)

Cerro Gordo County, IA

Midwest

Wind

Cimarron^(b)

Gray County, KS

Other South

Wind

166

Conestogo Wind

Wellington County, Ontario, Canada

Midwest

Wind

Crystal Lake I^(b)(c)

Hancock County, IA

Midwest

100

Wind

150

Crystal Lake II

Winnebago County, IA

Midwest

Wind

200

Crystal Lake III

Winnebago County, IA

Midwest

Wind

Day County Wind^(b)

Day County, SD

Midwest

Wind

Delaware Mountain

Culberson County, TX

Texas

Wind

Diablo Wind^(b)

Alameda County, CA

West

Wind

Elk City Wind^(b)

Roger Mills & Beckham Counties, OK

Other South

Wind

Elk City Wind II

Roger Mills & Beckham Counties, OK

Other South

Wind

101

Endeavor Wind

Osceola County, IA

Midwest

Wind

100

Endeavor Wind II

Osceola County, IA

Midwest

Wind

Ensign Wind

Gray County, KS

Other South

Wind

Ghost Pine Wind

Kneehill County, Alberta, Canada

West

Wind

Gray County

Gray County, KS

Other South

170

Wind

112

Green Mountain^(b)

Somerset County, PA

Northeast

Wind

Green Power

Riverside County, CA

West

Wind

Green Ridge Power

Alameda & Contra Costa Counties, CA

West

803

Wind

Hancock County^(b)

Hancock County, IA

Midwest

148

Wind

High Winds^(b)

Solano County, CA

West

Wind

162

Horse Hollow Wind^(b)

Taylor County, TX

Texas

142

Wind

213

Horse Hollow Wind II^(b)

Taylor & Nolan Counties, TX

Texas

130

Wind

299

Horse Hollow Wind III^(b)

Nolan County, TX

Texas

149

Wind

224

Indian Mesa

Pecos County, TX

Texas

125

Wind

King Mountain^(b)

Upton County, TX

Texas

214

Wind

278

Lake Benton II^(b)

Pipestone County, MN

Midwest

137

Wind

103

Langdon Wind^(b)(c)

Cavalier County, ND

Midwest

Wind

118

Langdon Wind II^(b)(c)

Cavalier County, ND

Midwest

Wind

Lee / DeKalb Wind

Lee & DeKalb Counties, IL

Midwest

145

Wind

217

Limon I^(b)(c)

Lincoln, Elbert & Arapahoe Counties, CO

West

125

Wind

200

Limon II^(b)(c)

Lincoln, Elbert & Arapahoe Counties, CO

West

125

Wind

200

Logan Wind^(c)

Logan County, CO

West

134

Wind

201

Majestic Wind^(b)(c)

Carson County, TX

Texas

Wind

Majestic Wind II^(b)(c)

Carson & Potter Counties, TX

Texas

Wind

Meyersdale^(b)

Somerset County, PA

Northeast

Wind

Mill Run^(b)

Fayette County, PA

Northeast

Wind

Minco Wind^(b)

Grady County, OK

Other South

Wind

Minco Wind II^(b)

Grady & Caddo Counties, OK

Other South

Wind

101

Minco Wind III

Grady, Caddo & Canadian Counties, OK

Other South

Wind

101

Mojave 3/4/5

Kern County, CA

West

246

Wind

Montezuma Wind^(b)

Solano County, CA

West

Wind

Montezuma Wind II^(b)(c)

Solano County, CA

West

Wind

Mount Copper^(b)

Gaspésie, Quebec, Canada

Midwest

Wind

Table of Contents

NEER Facilities

Location

Geographic

Region

No.

of Units

Fuel

Net

Capability

(mw)^(a)

Mount Miller^(b)

Gaspésie, Quebec, Canada

Midwest

Wind

Mountaineer Wind^(b)

Preston & Tucker Counties, WV

Northeast

Wind

Mower County Wind^(c)

Mower County, MN

Midwest

Wind

New Mexico Wind^(b)

Quay & Debaca Counties, NM

West

136

Wind

204

North Dakota Wind^(b)

LaMoure County, ND

Midwest

Wind

North Sky River

Kern County, CA

West

100

Wind

160

Northern Colorado^(b)

Logan County, CO

West

Wind

174

Oklahoma / Sooner Wind^(b)

Harper & Woodward Counties, OK

Other South

Wind

102

Oliver County Wind I^(c)

Oliver County, ND

Midwest

Wind

Oliver County Wind II^(c)

Oliver County, ND

Midwest

Wind

Peetz Table Wind^(c)

Logan County, CO

West

133

Wind

199

Perrin Ranch Wind^(b)

Coconino County, AZ

West

Wind

Pubnico Point^(b)

Yarmouth County, Nova Scotia, Canada

Midwest

Wind

Red Canyon Wind^(b)

Borden, Garza & Scurry Counties, TX

Texas

Wind

Red Mesa Wind

Cibola County, NM

West

Wind

102

Sky River^(b)

Kern County, CA

West

322

Wind

Somerset Wind Power^(b)

Somerset County, PA

Northeast

Wind

South Dakota Wind^(b)

Hyde County, SD

Midwest

Wind

Southwest Mesa^(b)

Upton & Crockett Counties, TX

Texas

106

Wind

Stateline^(b)

Umatilla County, OR and Walla Walla County, WA

West

454

Wind

300

Story County Wind^(b)(c)

Story County, IA

Midwest

100

Wind

150

Story County Wind II^(b)

Story & Hardin Counties, IA

Midwest

100

Wind

150

Tuscola Bay^(b)

Tuscola, Bay & Saginaw Counties, MI

Midwest

Wind

120

Vansycle^(b)

Umatilla County, OR

West

Wind

Vansycle II

Umatilla County, OR

West

Wind

Vasco Winds^(b)(c)

Contra Costa County, CA

West

Wind

Victory Garden^(b)

Kern County, CA

West

Wind

Waymart^(b)

Wayne County, PA

Northeast

Wind

Weatherford Wind^(b)

Custer & Washita Counties, OK

Other South

Wind

147

Wessington Springs Wind^(b)(c)

Jerauld County, SD

Midwest

Wind

White Oak^(b)(c)

McLean County, IL

Midwest

100

Wind

150

Wilton Wind^(b)

Burleigh County, ND

Midwest

Wind

Wilton Wind II^(b)(c)

Burleigh County, ND

Midwest

Wind

Windpower Partners 1990

Alameda & Contra Costa Counties, CA

West

141

Wind

Windpower Partners 1991

Alameda & Contra Costa Counties, CA

West

162

Wind

Windpower Partners 1991-92

Alameda & Contra Costa Counties, CA

West

223

Wind

Windpower Partners 1992

Alameda & Contra Costa Counties, CA

West

300

Wind

Windpower Partners 1993^(b)(c)

Riverside County, CA

West

Wind

Windpower Partners 1994

Culberson County, TX

Texas

107

Wind

Wolf Ridge Wind

Cooke County, TX

Texas

Wind

112

Woodward Mountain

Upton & Pecos Counties, TX

Texas

242

Wind

160

Wyoming Wind^(b)

Uinta County, WY

West

Wind

144

Investments in joint ventures^(b)

Kern County, CA

West

397

Wind

Total Wind

10,057

Contracted

Bayswater^(b)

Far Rockaway, NY

Northeast

Gas

Duane Arnold

Palo, IA

Midwest

Nuclear

431

^(d)

Hatch Solar

Hatch, NM

West

Solar CPV

Jamaica Bay^(b)

Far Rockaway, NY

Northeast

Gas/Oil

Marcus Hook 750^(b)

Marcus Hook, PA

Northeast

Gas

744

Moore Solar^(b)

Lambton County, Ontario, Canada

Northeast

Solar PV

Point Beach

Two Rivers, WI

Midwest

Nuclear

1,190

Sombra Solar^(b)

Lambton County, Ontario, Canada

Northeast

Solar PV

Investments in joint ventures:

SEGS III-IX^(b)

Kramer Junction & Harper Lake, CA

West

Solar Thermal

148

Other

Various

Northeast

^(e)

158

Total Contracted

2,826

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NEER Facilities

Location

Geographic

Region

No.

of Units

Fuel

Net

Capability

(mw)^(a)

Merchant

Forney

Forney, TX

Texas

Gas

1,792

Lamar Power Partners

Paris, TX

Texas

Gas

1,000

Maine - Cape, Wyman

Various - ME

Northeast

Oil

796

^(f)

Maine^(b)

Various - ME

Northeast

Hydro

351

^(g)

Marcus Hook 50

Marcus Hook, PA

Northeast

Gas

Paradise Solar

West Deptford, NJ

Northeast

Solar PV

Seabrook

Seabrook, NH

Northeast

Nuclear

1,100

^(h)

Investment in joint venture

Sayreville, NJ

Northeast

Gas

145

Total Merchant

5,239

TOTAL

18,122

______________________


(a)	Represents NEER's net ownership interest in plant capacity.


(b)	These generating facilities are encumbered by liens against their assets securing various financings.


(c)	NEER owns these wind facilities together with third-party investors with differential membership interests. See Note 1 - Sale of Differential Membership Interests.


(d)	Excludes Central Iowa Power Cooperative and Corn Belt Power Cooperative's combined share of 30%.


(e)	Represents plants with no more than 50% ownership using fuels such as natural gas and waste coal.


(f)	Excludes six other energy-related partners' combined share of 16%.


(g)	See Note 1 - Assets and Liabilities Associated with Assets Held for Sale for discussion of the pending sale of these facilities.


(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, 2012, FPL owned and operated 591 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	3,038		25
138	kv	1,577		53
115	kv	748		1
69	kv	165		14
Less than 69 kv		42,331		25,207
Total		48,965		25,300

______________________

(a) Includes approximately 75 miles owned jointly with JEA.

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 NEER's generating facilities are owned by NEER subsidiaries and a number of those facilities are encumbered by liens securing various financings. Additionally, certain of NEER's 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

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

Item 4. Mine Safety Disclosures

Not applicable

Table of Contents

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 NEE. NEE'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 NEE 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:



	2012						2011
Quarter	High		Low		Cash Dividends		High		Low		Cash Dividends
First	$	61.21	$	58.57	$	0.60	$	55.86	$	51.54	$	0.55
Second	$	68.96	$	61.20	$	0.60	$	58.98	$	54.16	$	0.55
Third	$	72.22	$	65.95	$	0.60	$	58.25	$	49.00	$	0.55
Fourth	$	72.21	$	66.05	$	0.60	$	61.20	$	51.33	$	0.55

The amount and timing of dividends payable on NEE's common stock are within the sole discretion of NEE'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 NEE's financial position and results of operations, legislative and regulatory developments affecting the electric utility industry in general and FPL in particular, competitive conditions, change in business mix and any other factors the Board of Directors deems relevant. The ability of NEE 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 NEE. In February 2013, NEE announced that it would increase its quarterly dividend on its common stock from $0.60 to $0.66 per share. See Management's Discussion - Liquidity and Capital Resources - Covenants with respect to dividend restrictions and Note 10 - Common Stock Dividend Restrictions regarding dividends paid by FPL to NEE.

As of the close of business on January 31, 2013, there were 24,339 holders of record of NEE's common stock.

Issuer Purchases of Equity Securities. Information regarding purchases made by NEE of its common stock during the three months ended December 31, 2012 is as follows:



Period	Total Number of Shares Purchased ^(a)	Average Price Paid Per Share		Total Number of Shares Purchased as Part of a Publicly Announced Program	Maximum Number of Shares that May Yet be Purchased Under the Program^(b)
10/1/2012 - 10/31/12	847	$	70.26	—	13,274,748
11/1/2012 - 11/30/12	516	$	66.49	—	13,274,748
12/1/2012 - 12/31/12	512	$	70.58	—	13,274,748
Total	1,875	$	69.31	—

______________________

(a)

Includes: (1) in October and November 2012, shares of common stock withheld from employees to pay certain withholding taxes upon the vesting of stock awards granted to such employees under the NextEra Energy, Inc. Amended and Restated Long-Term Incentive Plan (former LTIP); and (2) in December 2012, shares of common stock purchased as a reinvestment of dividends by the trustee of a grantor trust in connection with NEE's obligation under a February 2006 grant under the former LTIP to an executive officer of deferred retirement share awards.


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

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Item 6. Selected Financial Data



	Years Ended December 31,
	2012			2011			2010			2009			2008
SELECTED DATA OF NEE (millions, except per share amounts):
Operating revenues	$	14,256		$	15,341		$	15,317		$	15,643		$	16,410
Net income^(a)	$	1,911		$	1,923		$	1,957		$	1,615		$	1,639
Earnings per share of common stock - basic	$	4.59		$	4.62		$	4.77		$	3.99		$	4.10
Earnings per share of common stock - assuming dilution	$	4.56		$	4.59		$	4.74		$	3.97		$	4.07
Dividends paid per share of common stock	$	2.40		$	2.20		$	2.00		$	1.89		$	1.78
Total assets^(b)	$	64,439		$	57,188		$	52,994		$	48,458		$	44,821
Long-term debt, excluding current maturities	$	23,177		$	20,810		$	18,013		$	16,300		$	13,833
SELECTED DATA OF FPL (millions):
Operating revenues	$	10,114		$	10,613		$	10,485		$	11,491		$	11,649
Net income	$	1,240		$	1,068		$	945		$	831		$	789
Total assets	$	34,853		$	31,816		$	28,698		$	26,812		$	26,175
Long-term debt, excluding current maturities	$	8,329		$	7,483		$	6,682		$	5,794		$	5,311
Energy sales (kwh)	105,109			106,662			107,978			105,414			105,406
Energy sales:
Residential	50.8		%	51.2		%	52.2		%	51.2		%	50.5		%
Commercial	43.0			42.2			41.3			42.7			43.2
Industrial	2.9			2.9			2.9			3.1			3.4
Interchange power sales	0.7			0.9			0.8			1.4			1.6
Other^(c)	2.6			2.8			2.8			1.6			1.3
Total	100.0		%	100.0		%	100.0		%	100.0		%	100.0		%
Approximate 60-minute peak load (mw):^(d)
Summer season	21,440			21,619			22,256			22,351			21,060
Winter season	20,286			17,934			21,153			24,346			20,031
Average number of customer accounts (thousands):
Residential	4,052			4,027			4,004			3,984			3,992
Commercial	512			508			504			501			501
Industrial	9			9			9			10			13
Other	3			3			3			4			4
Total	4,576			4,547			4,520			4,499			4,510
Average price billed to customers (cents per kwh)	9.51			9.83			9.34			11.19			10.96

______________________

(a)

Includes net unrealized mark-to-market after-tax gains (losses) associated with non-qualifying hedges of $(34) million, $190 million, $175 million, $(20) million and $170 million and OTTI after-tax income (losses), net of OTTI reversals of $31 million, $(6) million, $4 million, $(13) million and $(76) million for the years ended December 31, 2012, 2011, 2010, 2009 and 2008, respectively. Also, 2011 includes an after-tax loss on the sale of natural gas-fired generating assets of approximately $98 million. See Note 4 - Nonrecurring Fair Value Measurements.


(b)	In 2012, includes assets held for sale of approximately $335 million. See Note 1 - Assets and Liabilities Associated with Assets Held for Sale.


(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 2012, through February 27, 2013).

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

OVERVIEW

NEE’s operating performance is driven primarily by the operations of its two principal subsidiaries, FPL, which serves approximately 4.6 million customer accounts in Florida and is one of the largest rate-regulated electric utilities in the U.S., and NEER, which together with affiliated entities is the largest generator in North America of renewable energy from the wind and sun. The table below presents NEE’s net income and earnings per share by reportable segment - FPL, NEER and Corporate and Other, which is primarily comprised of interest expense, the operating results of NEET, FPL FiberNet and other business activities, as well as other income and expense items, including income taxes and eliminating entries (see Note 14 for additional segment information). The discussion that follows should be read in conjunction with the Notes to the Consolidated Financial Statements contained herein. In the discussion below and in Results of Operations, all comparisons are with the corresponding items in the prior year.



	Net Income (Loss)							Earnings (Loss) Per Share, assuming dilution
	Years Ended December 31,							Years Ended December 31,
	2012			2011		2010		2012			2011		2010
	(millions)
FPL	$	1,240		$	1,068	$	945	$	2.96		$	2.55	$	2.29
NEER^(a)	687			774		980		1.64			1.85		2.37
Corporate and Other	(16		)	81		32		(0.04		)	0.19		0.08
NEE	$	1,911		$	1,923	$	1,957	$	4.56		$	4.59	$	4.74

______________________


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

For the five years ended December 31, 2012, NEE delivered a total shareholder return of approximately 22%, significantly outpacing the S&P 500’s 9% return, the S&P 500 Utilities' 2% return, the Dow Jones U.S. Electricity's 5% decline and the S&P 500 Electric Utilities’ 5% decline. The historical stock performance of NEE's common stock shown in the performance graph below is not necessarily indicative of future stock price performance.

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Adjusted Earnings

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

Adjusted earnings exclude the unrealized mark-to-market effect of non-qualifying hedges (as described below) and OTTI losses on securities held in NEER’s nuclear decommissioning funds, net of the reversal of previously recognized OTTI losses on securities sold and losses on securities where price recovery was deemed unlikely (collectively, OTTI reversals). However, other adjustments may be made from time to time with the intent to provide more meaningful and comparable results of ongoing operations. In 2011, adjusted earnings also excluded the after-tax loss on the sale of natural gas-fired generating assets (as described below).

NEE and NEER segregate into two categories unrealized mark-to-market gains and losses on energy derivative transactions which are used to manage commodity price risk. The first category, referred to as non-qualifying hedges, represents certain transactions entered into as economic hedges but the transactions do not meet the requirements for hedge accounting or hedge accounting treatment is not elected. Changes in the fair value of those transactions are marked to market and reported in the consolidated statements of income, resulting in earnings volatility because the economic offset to the positions, such as the physical assets from which power is generated, are not marked to market. As a consequence, NEE's net income reflects only the movement in one part of economically-linked transactions. For this reason, NEE's management views results expressed excluding the unrealized mark-to-market impact of the non-qualifying hedges as a meaningful measure of current period performance. The second category, referred to as trading activities, which is included in adjusted earnings, represents the net unrealized effect of actively traded positions entered into to take advantage of expected market price movements and all other commodity hedging activities. At FPL, substantially all changes in the fair value of energy derivative transactions are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the fuel clause or the capacity clause. See Note 3.

In late 2011, subsidiaries of NEER completed the sales of their ownership interests in five natural gas-fired generating plants with a total generating capacity of approximately 2,700 mw located in California, Virginia, Alabama, South Carolina and Rhode Island. In connection with these sales, a loss of approximately $151 million ($98 million total after-tax with $92 million of this loss recorded by NEER) was recorded in NEE's consolidated statements of income, which was excluded from adjusted earnings. See Note 4 - Nonrecurring Fair Value Measurements.

In late 2012, a subsidiary of NEER entered into an agreement to sell its ownership interest in a portfolio of hydropower generation plants and related assets with a total generating capacity of 351 mw located in Maine and New Hampshire. Upon the anticipated closing in the first quarter of 2013, NEER expects to record a gain which is expected to be excluded from 2013 adjusted earnings. The operations of these projects were not material to NEE's consolidated statements of income for the years ended December 31, 2012, 2011 and 2010 and the transaction is not expected to have a material effect on ongoing future financial results. See Note 1 - Assets and Liabilities Associated with Assets Held for Sale.

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



	Years Ended December 31,
	2012			2011			2010
				(millions)
Net unrealized mark-to-market after-tax gains (losses) from non-qualifying hedge activity^(a)	$	(34	)	$	190		$	175
Income (loss) from OTTI after-tax losses on securities held in NEER's nuclear decommissioning funds, net of OTTI reversals	$	31		$	(6	)	$	4
After-tax loss on sale of natural gas-fired generating assets^(b)	$	—		$	(98	)	$	—

______________________


(a)	$37 million of losses, $193 million of gains and $176 million of gains, respectively, are included in NEER's net income; the balance is included in Corporate and Other.


(b)	$92 million is included in NEER's net income; the balance is included in Corporate and Other.

The change in unrealized mark-to-market activity from non-qualifying hedges is primarily attributable to changes in forward power and natural gas prices, as well as the reversal of previously recognized unrealized mark-to-market gains or losses as the underlying transactions were realized. As a general rule, a gain (loss) in the non-qualifying hedge category is offset by decreases (increases) in the fair value of related physical asset positions in the portfolio or contracts, which are not marked to market under GAAP.

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2012 Summary

NEE's net income for 2012 was $12 million, or 3 cents per share, lower than 2011 primarily due to lower results at Corporate and Other and NEER, partly offset by higher earnings at FPL.

FPL's increase in net income in 2012 was primarily driven by investments in plant in service which resulted in higher use of FPL's surplus depreciation credit, as permitted under the 2010 rate agreement, to earn an 11% regulatory ROE on its retail rate base, as well as higher cost recovery clause results and higher AFUDC - equity. The 2010 rate agreement was effective through December 31, 2012. See Outlook below for a discussion of the 2012 rate agreement. FPL's planned smart meter installations throughout Florida are approximately 96% complete, with a cumulative total of 4.3 million smart meters installed. In 2012, FPL maintained a typical residential bill that was the lowest of all 55 utilities in Florida and 26% below the national average based on a rate per kwh as of July 2012.

NEER's earnings decreased in 2012 primarily due to net unrealized mark-to-market losses from non-qualifying hedge activity in 2012 compared to gains on such hedges in 2011 and lower results from the existing asset portfolio, partly offset by the absence of the loss on sale of natural gas-fired generating assets and impairment charges recorded in 2011 and higher results in 2012 from new investments and the customer supply and proprietary power and gas trading businesses. In 2012, NEER added over 1,500 mw of wind capacity, including its first wind project in the province of Ontario, Canada, and placed its 10,000^th mw of wind capacity into service.

Corporate and Other's earnings in 2012 decreased primarily due to the absence of state deferred income tax benefits related to state tax law changes and an income tax benefit related to the dissolution of a subsidiary recorded in 2011.

NEE and its subsidiaries, including FPL, require funds to support and grow their businesses. These funds are primarily provided by cash flow from operations and short- and long-term borrowings and, from time to time, issuance of equity securities. As of February 8, 2013, NEE's total net available liquidity was approximately $5.7 billion, of which FPL's portion was approximately $3.1 billion.

Outlook

FPL's 2012 rate agreement provides, among other things, base rate predictability through December 2016, including allowances for rate increases when the modernized Cape Canaveral, Rivera Beach and Port Everglades power plants are placed in service, and, as discussed in more detail below, permits FPL to amortize the reserve up to $400 million over the 2013 to 2016 period. FPL's allowed regulatory ROE over this period will be 10.50%, with a range of plus or minus 100 basis points.

NEE's strategy at both of its principal businesses seeks to meet customer needs more economically and reliably than competitors. Meeting customer needs frequently requires the commitment of large capital expenditures to projects that have long lives and such commitments are difficult to reverse once made. Both FPL and NEER have made commitments to a variety of major capital projects that are expected to be completed over the next several years. While NEE management believes that these projects individually and collectively are attractive investments with the potential to create value for shareholders, there can be no guarantee that all or any of these projects will be successful. Because of their importance, management focuses particular attention on these large projects.

In 2013, NEE expects to focus efforts in particular on the following initiatives:

At FPL:


•	Sustaining FPL's customer value proposition: The combination of low bills, good reliability and excellent customer service that FPL currently provides its customers is both an objective of FPL's strategy and an important contributor to its long-term business success. FPL seeks to, at a minimum, maintain and ideally improve its overall customer value proposition.


•	Major capital projects: FPL is currently engaged in a large capital expansion program and its objective is to bring these projects in on schedule and within budget. This program includes:


•	modernizing its Cape Canaveral, Riviera Beach and Port Everglades power plants to high-efficiency natural gas-fired units (approximately 1,200 mw each at Cape Canaveral and Riviera Beach and 1,280 mw at Port Everglades) to be placed in service by June 2013, June 2014 and mid-2016, respectively, and


•	adding at least 510 mw of capacity at its existing nuclear units at St. Lucie and Turkey Point, to be placed in service by the spring of 2013, of which approximately 395 mw are in service as of December 31, 2012.

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•

Natural gas pipeline: In December 2012, FPL issued an RFP to build a third major natural gas pipeline to serve peninsular Florida. The proposed new pipeline will have an upstream segment which originates at an existing hub in Western Alabama and ends at a new hub to be built in Central Florida. The downstream segment will originate at the new hub in Central Florida and connect with FPL's system in Martin County. FPL plans to propose a self-build option for the downstream segment of the pipeline, which, if selected, is expected to be built, owned and operated by a FERC-regulated affiliate. The FERC-regulated affiliate is prepared to consider investing in support of a selected upstream segment to facilitate timely construction. The bids are due in April 2013, with the winning proposal(s) expected to be selected by the end of June 2013. The pipeline will be subject to regulatory approvals.

At NEER:


•	Maintaining excellence in day-to-day operations: NEER has developed a track record of generally running its facilities reliably and cost-effectively. The company seeks to, at minimum, maintain and ideally improve its operating performance.

•

Solar: Add nearly 900 mw of new solar generation by 2016, including the completion of the construction of the Spain solar projects in 2013 (see Note 13 - Commitments for recent changes in law that could negatively affect the Spain solar projects), the 250 mw Genesis solar project in California, the 550 mw Desert Sunlight solar project in California, in which NEER has a 50% equity investment, and the 250 mw McCoy solar PV project located in the Mojave Desert near the Genesis and Desert Sunlight solar projects.


•	Wind: Add approximately 600 mw of new Canadian wind generation by the end of 2015 and 175 mw of new U.S. wind generation in 2013. Continue to develop a backlog for U.S. wind for 2013 and 2014 in light of the PTC extension under the Taxpayer Relief Act.

At Lone Star: Achieve commercial operations by the end of the first quarter of 2013 on approximately 330 miles of transmission lines and other associated facilities in Texas.

In addition, NEE and FPL devote effort to numerous other initiatives designed to support their long-term growth and development. There can be no guarantees that NEE or FPL will be successful in attaining their goals with respect to any of these initiatives.

For additional information on certain of the above matters, see Item 1. Business.

RESULTS OF OPERATIONS

NEE’s net income for 2012 was $1.91 billion, compared to $1.92 billion in 2011 and $1.96 billion in 2010. The decrease in 2012 net income was primarily due to the absence of certain income tax benefits at Corporate and Other recorded in 2011 and lower results at NEER, partly offset by improved results at FPL. The decrease in NEE’s 2011 net income was primarily driven by lower earnings at NEER, partly offset by improved results at FPL and income tax benefits at Corporate and Other.

NEE's effective income tax rate for all periods presented reflects PTCs for wind projects at NEER and deferred income tax benefits associated with convertible ITCs under the American Recovery and Reinvestment Act of 2009 (Recovery Act). PTCs and deferred income tax benefits associated with convertible ITCs can significantly affect NEE's effective income tax rate depending on the amount of pretax income. PTCs can be significantly affected by wind generation and by the roll off of PTCs on certain wind projects after ten years of production (PTC roll off). See Note 1 - Income Taxes, Note 1 - Sale of Differential Membership Interests and Note 6. Also see Item 1. Business - NEER - Generation and Other Operations - Policy Incentives for Renewable Energy Projects, for a discussion of the Taxpayer Relief Act.

FPL: Results of Operations

FPL’s net income for 2012, 2011 and 2010 was $1,240 million, $1,068 million and $945 million, respectively, representing an increase in 2012 of $172 million and an increase in 2011 of $123 million. 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.

In 2010 through 2012, FPL earned a regulatory ROE of 11.0%, as permitted by the 2010 rate agreement. In 2012 and in 2011, growth in earnings for FPL was driven by:


•	investment in plant in service which resulted in higher use of FPL's surplus depreciation credit to earn an 11.0% regulatory ROE on its retail rate base,


•	higher cost recovery clause results, and


•	for 2012, higher AFUDC - equity.

Beginning in 2013, FPL's allowed regulatory ROE range under the 2012 rate agreement is 9.50% to 11.50%.

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FPL's operating revenues consisted of the following:



	Years Ended December 31,
	2012			2011		2010
				(millions)
Retail base	$	4,246		$	4,217	$	4,190
Fuel cost recovery	3,815			4,416		4,090
Net deferral of retail fuel revenues	(44		)	—		—
Net repayment of previously deferred retail fuel revenues	—			—		356
Other cost recovery clauses and pass-through costs, net of any deferrals	1,858			1,751		1,638
Other, primarily pole attachment rentals, transmission and wholesale sales and customer-related fees	239			229		211
Total	$	10,114		$	10,613	$	10,485

Retail Base

As permitted by the 2010 rate agreement, in 2012 and 2011, FPL collected approximately $52 million and $101 million, respectively, in additional retail base revenues through the capacity clause related to the placement in service of WCEC Unit No. 3 in May 2011. Also included in 2012 retail base revenues were approximately $18 million of unbilled revenues associated with new retail base rates under the 2012 rate agreement (see FPSC Rate Orders below), which were billed in 2013. Additional base revenues of approximately $22 million were collected in 2012 related to new nuclear capacity which was placed in service in 2011, as permitted by the FPSC's nuclear cost recovery rule. In 2013, FPL expects to collect approximately $245 million of additional base revenues related to new nuclear capacity of approximately 365 mw, which was placed in service in 2012. A base rate increase pursuant to the 2010 FPSC rate order increased 2011 retail base revenues by approximately $8 million.

FPSC Rate Orders

During the period 2010 to 2012, FPL's base rates were established by the 2010 FPSC rate order and the 2010 rate agreement which, among other things, during this period:


•	provided an approximately $75 million base rate increase on an annualized basis, effective March 1, 2010, and


•	permitted FPL to vary the amount of surplus depreciation credit taken in any calendar year up to certain limits, provided that in any year of the 2010 rate agreement FPL was required to use enough surplus depreciation credit to maintain an earned regulatory ROE within the range of 9.0% - 11.0%.

During 2012, 2011 and 2010, FPL recorded $480 million, $187 million and $4 million of surplus depreciation credit. See Item 1. Business - FPL - FPL Regulation for additional information on the 2010 FPSC rate order and the 2010 rate agreement.

Effective January 2013 through December 2016, FPL's base rates will be determined by the 2012 rate agreement, which was approved by the FPSC in January 2013. Key elements of the 2012 rate agreement include, among other things, the following:


•	New retail base rates and charges were established in January 2013 resulting in an increase in retail base revenues of $350 million on an annualized basis.


•	FPL's allowed regulatory ROE will be 10.50%, with a range of plus or minus 100 basis points. If FPL's earned regulatory ROE falls below 9.50%, FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.50%, any party to the 2012 rate agreement other than FPL may seek a review of FPL's retail base rates.


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


•	Cost recovery of WCEC Unit No. 3, which was placed in service in May 2011, will continue to occur through the capacity clause; however, such recovery will not be limited to the projected annual fuel cost savings as was the case in the previous rate agreement.

•

Subject to certain conditions, FPL must amortize, over the term of the 2012 rate agreement, a depreciation reserve surplus remaining at the end of 2012 under the 2010 rate order (approximately $224 million) and may amortize a portion of FPL's fossil dismantlement reserve up to a maximum of $176 million (collectively, the reserve), provided that in any year of the 2012 rate agreement, FPL must amortize at least enough reserve to maintain a 9.50% earned regulatory ROE but may not amortize any reserve that would result in an earned regulatory ROE in excess of 11.50%. The reserve will be amortized as a reduction of regulatory liabilities - accrued asset removal costs on NEE's and FPL's consolidated balance sheets.

•

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On February 7, 2013, the Office of Public Counsel filed a notice of appeal to the Florida Supreme Court of the FPSC's final order regarding the 2012 rate agreement.

Retail Customer Usage and Growth

In each of the years ended December 31, 2012 and 2011, FPL experienced a 2.0% decrease in average usage per retail customer, primarily due to weather conditions partly offset in 2012 by higher non-weather related usage per retail customer, which decreased retail base revenues by approximately $90 million and $107 million, respectively. The usage per retail customer data for the year ended December 31, 2011 includes three extra days of sales after adjusting for a change from a fiscal month to a calendar month. For both years ended December 31, 2012 and 2011, FPL experienced a 0.6% increase in the average number of customer accounts, increasing retail base revenues by approximately $27 million and $25 million, respectively.

Non-weather related usage per retail customer increased in 2012 mirroring the continued gradual improvements in the Florida economy. As of December 2012, Florida has experienced 29 consecutive months of positive year-over-year employment growth. The state's unemployment rate has fallen from a high of 11.4% in January 2010 to 8.0% in December 2012. The number of empty homes in FPL's service area is also gradually declining. The number of inactive meters (premises where electric service is available but no customer is requesting electric service) declined by 6.4% in 2012 while the number of low usage accounts decreased by 1.3%. At the same time, higher energy efficiencies are offsetting some of the increase in non-weather related usage per retail customer resulting from the improved economic outlook.

FPL has now experienced three consecutive years of moderately positive growth in the average number of customer accounts. Some improvement in the rate of customer growth is expected in 2013, assuming no significant decline in the overall state of Florida's economy.

Cost Recovery Clauses

Revenues from fuel and other cost recovery clauses and pass-through costs, such as franchise fees, revenue taxes and storm-related surcharges, are largely a pass-through of costs. Such revenues also include a return on investment allowed to be recovered through the cost recovery clauses on certain assets, primarily related to nuclear capacity, solar and environmental projects. In 2012, 2011 and 2010, cost recovery clauses contributed $160 million, $108 million and $75 million, respectively, to FPL’s net income. The increase in 2012 in cost recovery clause results was primarily due to a return related to additional nuclear capacity investments, while the increase in 2011 reflects a return related to additional solar, environmental and nuclear capacity investments. In 2013, it is expected that earnings from cost recovery clauses will decline primarily as a result of the collection in 2013 of retail base revenues related to new nuclear capacity which was placed in service in 2012 (see Retail Base above). Fluctuations in fuel cost recovery revenues are primarily driven by changes in fuel and energy charges which are included in fuel, purchased power and interchange expense in the consolidated statements of income, as well as by changes in energy sales. Fluctuations in revenues from other cost recovery clauses and pass-through costs are primarily driven by changes in storm-related surcharges, capacity charges, franchise fee costs, the impact of changes in O&M and depreciation expenses on the underlying cost recovery clause, investment in solar and environmental projects, investment in nuclear capacity until such capacity goes into service and is recovered in base rates, pre-construction costs associated with the development of two additional nuclear units at the Turkey Point site and changes in energy sales. Capacity charges 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. Underrecovery or overrecovery of cost recovery clause and other pass-through costs can significantly affect NextEra Energy's and FPL's operating cash flows. The change from December 31, 2011 to December 31, 2012 in deferred clause and franchise expenses and in deferred clause and franchise revenues was approximately $129 million and positively affected NEE’s and FPL’s cash flows from operating activities for the year ended December 31, 2012.

Risk Management Fuel Procurement Program

FPL uses a risk management fuel procurement program which was approved by the FPSC. The FPSC reviews the program activities and results for prudence on an annual basis as part of its annual review of fuel costs. The program is intended to manage fuel price volatility by locking in fuel prices for a portion of FPL’s fuel requirements. The current regulatory asset for the change in fair value of derivative instruments used in the fuel procurement program was approximately $16 million and $502 million at December 31, 2012 and 2011, respectively.

The decrease in fuel cost recovery revenues in 2012 is primarily due to a lower average fuel factor of approximately $558 million and lower energy sales of $43 million. The increase in fuel cost recovery revenues in 2011 reflects the absence of a $404 million one-time credit to retail customers’ bills made in 2010 pursuant to an FPSC order, partly offset by approximately $41 million related to lower energy sales and $37 million related to a lower average fuel factor.

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Other

The increase in revenues from other cost recovery clauses and pass-through costs in 2012 is primarily due to higher revenues associated with the FPSC’s nuclear cost recovery rule reflective of higher earnings on additional nuclear capacity investments. The nuclear cost recovery rule provides for the recovery of prudently incurred pre-construction costs and carrying charges (equal to a fixed pretax AFUDC rate) on construction costs and a return on investment for new nuclear capacity through levelized charges under the capacity clause. 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 effective beginning the following January.

Other Items Impacting FPL Results

Fuel, Purchased Power and Interchange

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



	Years Ended December 31,
	2012		2011		2010
			(millions)
Fuel and energy charges during the period	$	3,657	$	4,237	$	4,714
Net collection of previously deferred retail fuel costs	103		159		—
Net deferral of retail fuel costs	—		—		(276		)
Other, primarily capacity charges, net of any capacity deferral	505		581		544
Total	$	4,265	$	4,977	$	4,982

The decrease in fuel and energy charges in 2012 reflects lower fuel and energy prices of $526 million and lower energy sales of $54 million. The decrease in fuel and energy charges in 2011 reflects lower fuel and energy prices of approximately $415 million and lower energy sales of $62 million.

O&M Expenses

FPL's O&M expenses increased $74 million in 2012 primarily due to higher employee-related and insurance costs, as well as higher fossil plant outage costs primarily due to timing. Also, FPL's O&M expenses in 2012 reflect higher cost recovery clause costs of approximately $21 million, which did not significantly affect net income. FPL’s O&M expenses increased $79 million in 2011 primarily due to higher cost recovery clause costs.

Depreciation and Amortization Expense

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



	Years Ended December 31,
	2012			2011			2010
				(millions)
Surplus depreciation credit recorded under the 2010 rate agreement	$	(480	)	$	(187	)	$	(4	)
Other depreciation and amortization recovered under base rates	1,013			944			891
Depreciation and amortization recovered under cost recovery clauses and securitized storm-recovery cost amortization	126			41			121
Total	$	659		$	798		$	1,008

Under the terms of the 2010 rate agreement, FPL could 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 over the 2010 to 2012 period. See FPSC Rate Orders above for additional information on the use of the remaining depreciation reserve surplus. The increase in surplus depreciation credit recorded under the 2010 rate agreement in 2012 and 2011 is primarily a result of increased plant investment and enabled FPL to earn its 11.0% regulatory ROE. The increase in other depreciation and amortization expense recovered under base rates in 2012 and 2011 is primarily due to higher plant in service balances. The increase in depreciation and amortization recovered under cost recovery clauses and securitized storm-recovery cost amortization in 2012 is primarily due to true ups of prior year recoveries under the FPSC's nuclear cost recovery rule, while the decrease in such depreciation in 2011 is primarily due to lower depreciation and amortization under the FPSC's nuclear cost recovery rule. See Note 1 - Electric Plant, Depreciation and Amortization.

Taxes Other Than Income Taxes and Other

Taxes other than income taxes and other decreased $3 million in 2012 primarily due to lower franchise fees and revenue taxes (collectively, $31 million), both of which are pass-through costs and reflect the decrease in fuel cost recovery clause revenues, partly offset by higher property taxes of $28 million reflecting growth in plant in service balances. The increase in 2011 of $37 million was primarily due to higher franchise fees and revenue taxes, reflecting the increase in revenues from fuel and other cost recovery clauses and pass-through costs, and higher property taxes of $5 million reflecting growth in plant in service balances partly offset by a lower average property tax rate.

Table of Contents

Interest Expense

The increase in interest expense in 2012 is primarily due to higher average debt balances, partly offset by lower average interest rates, lower interest expense on customer deposits reflecting lower rates and lower average customer deposit balances and higher AFUDC - debt. The change in AFUDC - debt is due to the same factors as described below in AFUDC - equity. The increase in interest expense in 2011 is primarily due to higher average interest rates and higher average debt balances. Interest expense on storm-recovery bonds, as well as certain other interest expense on clause-recoverable investments (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 2012, 2011 and 2010 amounted to approximately $81 million, $65 million and $56 million, respectively. The increase in clause interest in 2012 and 2011 is primarily due to higher interest associated with nuclear capacity and environmental investments and, in 2011, also reflects higher interest associated with solar investments.

AFUDC - Equity

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

NEER: Results of Operations

NEER’s net income for 2012, 2011 and 2010 was $687 million, $774 million and $980 million, respectively, resulting in a decrease in 2012 of $87 million and a decrease in 2011 of $206 million. The primary drivers, on an after-tax basis, of these decreases were as follows:



	Increase (Decrease) From Prior Period
	Years Ended December 31,
	2012			2011
	(millions)
New investments^(a)	$	91		$	(26	)
Existing assets:^(a)
Wind	(86		)	96
Merchant	(59		)	(93		)
Contracted	(33		)	23
Total existing assets	(178		)	26
Gas infrastructure^(b)	24			23
Customer supply and proprietary power and gas trading businesses^(b)	44			(92		)
Asset sales and restructuring activities	20			(18		)
Impairment charges	31			(20		)
Interest expense, differential membership costs and other	(18		)	(14		)
Change in unrealized mark-to-market non-qualifying hedge activity^(c)(d)	(230		)	17
Loss on sale of natural gas-fired generating assets^(e)	92			(92		)
Change in OTTI losses on securities held in nuclear decommissioning funds, net of OTTI reversals^(d)	37			(10		)
Net income decrease	$	(87	)	$	(206	)

______________________

(a)

Includes PTCs and state ITCs on wind projects and, for new investments, deferred income tax and other benefits associated with convertible ITCs (see Note 1 -Electric Plant, Depreciation and Amortization, Note 1 - Income Taxes, Note 1 - Sale of Differential Membership Interests 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)	Does not include allocation of interest expense or corporate general and administrative expenses.


(c)	See Note 3 and Overview related to derivative instruments.


(d)	See table in Overview for additional detail.


(e)	See Note 4 - Nonrecurring Fair Value Measurements and Overview for additional information.

New Investments

In 2012, results from new investments increased primarily due to:


•	the addition of approximately 1,899 mw of wind and 45 mw of solar generation during or after 20

FLORIDA POWER & LIGHT CO 10-K