NEXTERA ENERGY INC
10-Ks and 10-Qs
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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended
September 30, 2013
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Commission
File
Number
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Exact name of registrants as specified in their
charters, address of principal executive offices and
registrants' telephone number
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IRS Employer
Identification
Number
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1-8841
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NEXTERA ENERGY, INC.
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59-2449419
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2-27612
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FLORIDA POWER & LIGHT COMPANY
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59-0247775
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700 Universe Boulevard
Juno Beach, Florida 33408
(561) 694-4000
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State or other jurisdiction of incorporation or organization: Florida
Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months and (2) have been subject to such filing requirements for the past 90 days.
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NextEra Energy, Inc. Yes
þ
No
o
Florida Power & Light Company Yes
þ
No
o
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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.
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NextEra Energy, Inc. Yes
þ
No
o
Florida Power & Light Company Yes
þ
No
o
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Indicate by check mark whether the registrants are a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Securities Exchange Act of 1934.
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NextEra Energy, Inc.
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Large Accelerated Filer
þ
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Accelerated Filer
¨
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Non-Accelerated Filer
¨
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Smaller Reporting Company
¨
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Florida Power & Light Company
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Large Accelerated Filer
¨
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Accelerated Filer
¨
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Non-Accelerated Filer
þ
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Smaller Reporting Company
¨
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Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Securities Exchange Act of 1934). Yes
¨
No
þ
The number of shares outstanding of NextEra Energy, Inc. common stock, as of the latest practicable date: Common Stock,
$0.01
par value, outstanding as of
September 30, 2013
:
430,681,556
shares.
As of
September 30, 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.
This combined Form 10-Q represents separate filings by NextEra Energy, Inc. and Florida Power & Light Company. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Florida Power & Light Company makes no representations as to the information relating to NextEra Energy, Inc.'s other operations.
Florida Power & Light Company meets the conditions set forth in General Instruction H.(1)(a) and (b) of Form 10-Q and is therefore filing this Form with the reduced disclosure format.
TABLE OF CONTENTS
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Page No.
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PART I - FINANCIAL INFORMATION
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PART II - OTHER INFORMATION
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NextEra Energy, Inc., Florida Power & Light Company, NextEra Energy Capital Holdings, Inc. and NextEra Energy Resources, LLC each has subsidiaries and affiliates with names that may include NextEra Energy, FPL, NextEra Energy Resources, FPL Group Capital, FPL Energy, FPLE and similar references. For convenience and simplicity, in this report the terms NEE, FPL, NEECH and NEER are sometimes used as abbreviated references to specific subsidiaries, affiliates or groups of subsidiaries or affiliates. The precise meaning depends on the context.
2
FORWARD-LOOKING STATEMENTS
This report includes forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Any statements that express, or involve discussions as to, expectations, beliefs, plans, objectives, assumptions, strategies, future events or performance (often, but not always, through the use of words or phrases such as 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, the following important factors (in addition to any assumptions and other factors referred to specifically in connection with such forward-looking statements) that could have a significant impact on NextEra Energy, Inc.'s (NEE) and/or Florida Power & Light Company's (FPL) operations and financial results, and could cause NEE's and/or FPL's actual results to differ materially from those contained or implied in forward-looking statements made by or on behalf of NEE and/or FPL in this combined Form 10-Q, in presentations, on their respective websites, in response to questions or otherwise.
Regulatory, Legislative and Legal Risks
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NEE's and FPL's business, financial condition, results of operations and prospects may be adversely affected by the extensive regulation of their business.
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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.
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Regulatory decisions that are important to NEE and FPL may be materially adversely affected by political, regulatory and economic factors.
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FPL's use of derivative instruments could be subject to prudence challenges and, if found imprudent, could result in disallowances of cost recovery for such use by the Florida Public Service Commission (FPSC).
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Any reductions to, or the elimination of, governmental incentives that support renewable energy, including, but not limited to, tax incentives, renewable portfolio standards (RPS) or feed-in tariffs, or the imposition of additional taxes or other assessments on renewable energy, could result in, among other items, the lack of a satisfactory market for the development of new renewable energy projects, NextEra Energy Resources, LLC (NEER) abandoning the development of renewable energy projects, a loss of NEER's investments in renewable energy projects and reduced project returns, any of which could have a material adverse effect on NEE's business, financial condition, results of operations and prospects.
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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.
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NEE's and FPL's business, financial condition, results of operations and prospects could be materially adversely affected if the rules implementing the Dodd-Frank Wall Street Reform and Consumer Protection Act broaden the scope of its provisions regarding the regulation of over-the-counter (OTC) financial derivatives and make them applicable to NEE and FPL.
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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.
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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.
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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.
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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.
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NEE's and FPL's business, financial condition, results of operations and prospects may be materially adversely affected due to adverse results of litigation.
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Operational Risks
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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.
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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.
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The operation and maintenance of NEE's and FPL's electric generation, transmission and distribution facilities, gas infrastructure facilities and other facilities are subject to many operational risks, the consequences of which could have a material adverse effect on NEE's and FPL's business, financial condition, results of operations and prospects.
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3
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NEE's and FPL's business, financial condition, results of operations and prospects may be negatively affected by a lack of growth or slower growth in the number of customers or in customer usage.
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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.
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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.
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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.
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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.
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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.
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Sales of power on the spot market or on a short-term contractual basis may cause NEE's results of operations to be volatile.
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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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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.
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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.
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NEE and FPL are subject to credit and performance risk from customers, hedging counterparties and vendors.
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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.
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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.
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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.
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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.
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NEE and FPL may be adversely affected by negative publicity.
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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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Increasing costs associated with health care plans may materially adversely affect NEE's and FPL's results of operations.
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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.
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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.
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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.
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Nuclear Generation Risks
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The construction, operation and maintenance of NEE's and FPL's nuclear generation facilities involve environmental, health and financial risks that could result in fines or the closure of the facilities and in increased costs and capital expenditures.
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In the event of an incident at any nuclear generation facility in the United States (U.S.) or at certain nuclear generation facilities in Europe, NEE and FPL could be assessed significant retrospective assessments and/or retrospective insurance premiums as a result of their participation in a secondary financial protection system and nuclear insurance mutual companies.
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4
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U.S. Nuclear Regulatory Commission (NRC) orders or new regulations related to increased security measures and any future safety requirements promulgated by the NRC could require NEE and FPL to incur substantial operating and capital expenditures at their nuclear generation facilities.
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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.
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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.
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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.
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Liquidity, Capital Requirements and Common Stock Risks
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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.
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NEE's, NextEra Energy Capital Holdings, Inc.'s (NEECH) and FPL's inability to maintain their current credit ratings may adversely affect NEE's and FPL's liquidity and results of operations, limit the ability of NEE and FPL to grow their business, and increase interest costs.
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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.
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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.
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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.
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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.
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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.
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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.
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Disruptions, uncertainty or volatility in the credit and capital markets may exert downward pressure on the market price of NEE's common stock.
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These factors should be read together with the risk factors included in Part I, Item 1A. Risk Factors in NEE's and FPL's Annual Report on Form 10-K for the year ended December 31, 2012 (2012 Form 10-K), and investors should refer to that section of the 2012 Form 10-K. Any forward-looking statement speaks only as of the date on which such statement is made, and NEE and FPL undertake no obligation to update any forward-looking statement to reflect events or circumstances, including, but not limited to, unanticipated events, after the date on which such statement is made, unless otherwise required by law. New factors emerge from time to time and it is not possible for management to predict all of such factors, nor can it assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained or implied in any forward-looking statement.
Website Access to U.S. Securities and Exchange Commission (SEC) Filings.
NEE and FPL make their SEC filings, including the annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports, available free of charge on NEE's internet website, www.nexteraenergy.com, as soon as reasonably practicable after those documents are electronically filed with or furnished to the SEC. The information and materials available on NEE's website (or any of its subsidiaries' websites) are not incorporated by reference into this combined Form 10-Q. The SEC maintains an internet website that contains reports, proxy and information statements and other information regarding registrants that file electronically with the SEC at www.sec.gov.
5
NEXTERA ENERGY, INC.
(millions, except per share amounts)
(unaudited)
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Three Months Ended September 30,
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Nine Months Ended September 30,
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2013
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2012
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2013
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2012
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OPERATING REVENUES
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$
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4,394
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$
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3,843
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$
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11,506
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$
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10,881
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OPERATING EXPENSES
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Fuel, purchased power and interchange
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1,438
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1,526
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3,766
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3,943
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Other operations and maintenance
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818
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776
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2,338
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2,347
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Impairment charge
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—
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—
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300
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—
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Depreciation and amortization
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605
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467
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1,523
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1,121
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Taxes other than income taxes and other
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348
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332
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978
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925
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Total operating expenses
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3,209
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3,101
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8,905
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8,336
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OPERATING INCOME
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1,185
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742
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2,601
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2,545
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OTHER INCOME (DEDUCTIONS)
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Interest expense
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(288
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)
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(259
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)
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(825
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)
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(795
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)
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Benefits associated with differential membership interests - net
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37
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7
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119
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70
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Allowance for equity funds used during construction
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12
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21
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50
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52
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Interest income
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20
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20
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58
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62
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Gains on disposal of assets - net
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20
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53
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40
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120
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Other - net
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9
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(15
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)
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27
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(19
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)
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Total other deductions - net
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(190
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)
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(173
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)
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(531
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)
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(510
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)
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INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
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995
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569
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2,070
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2,035
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INCOME TAXES
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297
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154
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677
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553
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INCOME FROM CONTINUING OPERATIONS
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698
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415
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1,393
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1,482
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NET GAIN FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES
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—
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—
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188
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—
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NET INCOME
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$
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698
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$
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415
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$
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1,581
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$
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1,482
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Basic earnings per share of common stock:
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Continuing operations
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$
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1.65
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$
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0.99
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$
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3.30
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$
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3.57
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Discontinued operations
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—
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—
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0.44
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—
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Net income
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$
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1.65
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$
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0.99
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$
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3.74
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$
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3.57
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Earnings per share of common stock - assuming dilution:
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Continuing operations
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$
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1.64
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$
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0.98
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$
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3.28
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$
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3.55
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Discontinued operations
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—
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—
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0.44
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—
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Net income
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$
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1.64
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$
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0.98
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$
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3.72
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$
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3.55
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Dividends per share of common stock
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$
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0.66
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$
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0.60
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$
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1.98
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$
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1.80
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Weighted-average number of common shares outstanding:
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Basic
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423.8
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419.3
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422.2
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415.6
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Assuming dilution
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426.8
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421.7
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424.8
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418.0
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This report should be read in conjunction with the Notes to Condensed Consolidated Financial Statements (Notes) herein and the Notes to Consolidated Financial Statements appearing in the
2012
Form 10-K.
6
NEXTERA ENERGY, INC.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(millions)
(unaudited)
|
|
Three Months Ended September 30,
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Nine Months Ended September 30,
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|||||||||||||
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2013
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2012
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2013
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2012
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NET INCOME
|
$
|
698
|
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$
|
415
|
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$
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1,581
|
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$
|
1,482
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OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX
|
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Net unrealized gains (losses) on cash flow hedges:
|
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|
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Effective portion of net unrealized gains (losses) (net of $7 and $15 tax benefit, $45 tax expense and $41 tax benefit, respectively)
|
(18
|
)
|
(30
|
)
|
83
|
|
(79
|
)
|
|||||||
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Reclassification from accumulated other comprehensive income to net income (net of $5, $7, $27 and $18 tax expense, respectively)
|
9
|
|
3
|
|
48
|
|
24
|
|
|||||||
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Net unrealized gains (losses) on available for sale securities:
|
|
|
|
|
|
|
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|||||||
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Net unrealized gains on securities still held (net of $22, $18, $49 and $44 tax expense, respectively)
|
30
|
|
26
|
|
72
|
|
64
|
|
|||||||
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Reclassification from accumulated other comprehensive income to net income (net of $4, $18, $11 and $43 tax benefit, respectively)
|
(7
|
)
|
(27
|
)
|
(17
|
)
|
(64
|
)
|
|||||||
|
Defined benefit pension and other benefits plans (net of less than a million, less than a million, $5 tax expense and $3 tax benefit, respectively)
|
—
|
|
—
|
|
7
|
|
(6
|
)
|
|||||||
|
Net unrealized gains (losses) on foreign currency translation (net of $2 and $2 tax expense, $13 tax benefit and $3 tax expense, respectively)
|
6
|
|
3
|
|
(26
|
)
|
6
|
|
|||||||
|
Other comprehensive income (loss) related to equity method investee (net of less than a million, $3 tax benefit, $4 tax expense and $7 tax benefit, respectively)
|
—
|
|
(4
|
)
|
6
|
|
(10
|
)
|
|||||||
|
Total other comprehensive income (loss), net of tax
|
20
|
|
(29
|
)
|
173
|
|
(65
|
)
|
|||||||
|
COMPREHENSIVE INCOME
|
$
|
718
|
|
$
|
386
|
|
$
|
1,754
|
|
$
|
1,417
|
|
|||
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the
2012
Form 10-K.
7
NEXTERA ENERGY, INC.
(millions, except par value)
(unaudited)
|
|
September 30,
2013 |
December 31,
2012 |
|||||
|
PROPERTY, PLANT AND EQUIPMENT
|
|
|
|||||
|
Electric plant in service and other property
|
$
|
61,355
|
|
$
|
57,054
|
|
|
|
Nuclear fuel
|
1,938
|
|
1,895
|
|
|||
|
Construction work in progress
|
4,562
|
|
5,968
|
|
|||
|
Less accumulated depreciation and amortization
|
(16,456
|
)
|
(15,504
|
)
|
|||
|
Total property, plant and equipment - net ($4,646 and $4,487 related to VIEs, respectively)
|
51,399
|
|
49,413
|
|
|||
|
CURRENT ASSETS
|
|
|
|
|
|||
|
Cash and cash equivalents
|
558
|
|
329
|
|
|||
|
Customer receivables, net of allowances of $15 and $10, respectively
|
1,888
|
|
1,487
|
|
|||
|
Other receivables
|
353
|
|
569
|
|
|||
|
Materials, supplies and fossil fuel inventory
|
1,142
|
|
1,073
|
|
|||
|
Regulatory assets:
|
|||||||
|
Deferred clause and franchise expenses
|
124
|
|
75
|
|
|||
|
Other
|
170
|
|
113
|
|
|||
|
Derivatives
|
441
|
|
517
|
|
|||
|
Deferred income taxes
|
8
|
|
397
|
|
|||
|
Assets held for sale
|
—
|
|
335
|
|
|||
|
Other
|
788
|
|
342
|
|
|||
|
Total current assets
|
5,472
|
|
5,237
|
|
|||
|
OTHER ASSETS
|
|
|
|
|
|||
|
Special use funds
|
4,574
|
|
4,190
|
|
|||
|
Other investments
|
1,085
|
|
976
|
|
|||
|
Prepaid benefit costs
|
1,058
|
|
1,031
|
|
|||
|
Regulatory assets:
|
|
|
|
|
|||
|
Securitized storm-recovery costs ($238 and $274 related to a VIE, respectively)
|
388
|
|
461
|
|
|||
|
Other
|
677
|
|
582
|
|
|||
|
Derivatives
|
1,011
|
|
920
|
|
|||
|
Other
|
1,502
|
|
1,629
|
|
|||
|
Total other assets
|
10,295
|
|
9,789
|
|
|||
|
TOTAL ASSETS
|
$
|
67,166
|
|
$
|
64,439
|
|
|
|
CAPITALIZATION
|
|
|
|
|
|||
|
Common stock ($0.01 par value, authorized shares - 800; outstanding shares - 431 and 424, respectively)
|
$
|
4
|
|
$
|
4
|
|
|
|
Additional paid-in capital
|
5,959
|
|
5,536
|
|
|||
|
Retained earnings
|
11,528
|
|
10,783
|
|
|||
|
Accumulated other comprehensive loss
|
(82
|
)
|
(255
|
)
|
|||
|
Total common shareholders' equity
|
17,409
|
|
16,068
|
|
|||
|
Long-term debt ($1,134 and $1,369 related to VIEs, respectively)
|
23,862
|
|
23,177
|
|
|||
|
Total capitalization
|
41,271
|
|
39,245
|
|
|||
|
CURRENT LIABILITIES
|
|
|
|
|
|||
|
Commercial paper
|
915
|
|
1,211
|
|
|||
|
Short-term debt
|
—
|
|
200
|
|
|||
|
Current maturities of long-term debt
|
3,933
|
|
2,771
|
|
|||
|
Accounts payable
|
1,244
|
|
1,281
|
|
|||
|
Customer deposits
|
502
|
|
508
|
|
|||
|
Accrued interest and taxes
|
783
|
|
414
|
|
|||
|
Derivatives
|
615
|
|
430
|
|
|||
|
Accrued construction-related expenditures
|
450
|
|
427
|
|
|||
|
Liabilities associated with assets held for sale
|
—
|
|
733
|
|
|||
|
Other
|
771
|
|
904
|
|
|||
|
Total current liabilities
|
9,213
|
|
8,879
|
|
|||
|
OTHER LIABILITIES AND DEFERRED CREDITS
|
|
|
|
|
|||
|
Asset retirement obligations
|
1,808
|
|
1,715
|
|
|||
|
Deferred income taxes
|
7,207
|
|
6,703
|
|
|||
|
Regulatory liabilities:
|
|
|
|
|
|||
|
Accrued asset removal costs
|
1,784
|
|
1,950
|
|
|||
|
Asset retirement obligation regulatory expense difference
|
1,987
|
|
1,813
|
|
|||
|
Other
|
391
|
|
309
|
|
|||
|
Derivatives
|
354
|
|
587
|
|
|||
|
Deferral related to differential membership interests - VIEs
|
1,828
|
|
1,784
|
|
|||
|
Other
|
1,323
|
|
1,454
|
|
|||
|
Total other liabilities and deferred credits
|
16,682
|
|
16,315
|
|
|||
|
COMMITMENTS AND CONTINGENCIES
|
|
|
|
|
|||
|
TOTAL CAPITALIZATION AND LIABILITIES
|
$
|
67,166
|
|
$
|
64,439
|
|
|
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the
2012
Form 10-K.
8
NEXTERA ENERGY, INC.
(millions)
(unaudited)
|
Nine Months Ended September 30,
|
|||||||
|
2013
|
2012
|
||||||
|
CASH FLOWS FROM OPERATING ACTIVITIES
|
|||||||
|
Net income
|
$
|
1,581
|
|
$
|
1,482
|
|
|
|
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
|
|
|
|
|
|||
|
Depreciation and amortization
|
1,523
|
|
1,121
|
|
|||
|
Nuclear fuel and other amortization
|
262
|
|
204
|
|
|||
|
Impairment charge
|
300
|
|
—
|
|
|||
|
Unrealized gains on marked to market energy contracts
|
(84
|
)
|
(89
|
)
|
|||
|
Deferred income taxes
|
823
|
|
517
|
|
|||
|
Cost recovery clauses and franchise fees
|
(126
|
)
|
115
|
|
|||
|
Benefits associated with differential membership interests - net
|
(119
|
)
|
(70
|
)
|
|||
|
Allowance for equity funds used during construction
|
(50
|
)
|
(52
|
)
|
|||
|
Gains on disposal of assets - net
|
(40
|
)
|
(120
|
)
|
|||
|
Net gain from discontinued operations, net of income taxes
|
(188
|
)
|
—
|
|
|||
|
Other - net
|
131
|
|
240
|
|
|||
|
Changes in operating assets and liabilities:
|
|
|
|
|
|||
|
Customer and other receivables
|
(384
|
)
|
(347
|
)
|
|||
|
Materials, supplies and fossil fuel inventory
|
(69
|
)
|
21
|
|
|||
|
Other current assets
|
(4
|
)
|
(51
|
)
|
|||
|
Other assets
|
(23
|
)
|
(50
|
)
|
|||
|
Accounts payable
|
128
|
|
1
|
|
|||
|
Margin cash collateral
|
(448
|
)
|
110
|
|
|||
|
Income taxes
|
(120
|
)
|
(6
|
)
|
|||
|
Interest and other taxes
|
350
|
|
270
|
|
|||
|
Other current liabilities
|
(17
|
)
|
(27
|
)
|
|||
|
Other liabilities
|
(36
|
)
|
(112
|
)
|
|||
|
Net cash provided by operating activities
|
3,390
|
|
3,157
|
|
|||
|
CASH FLOWS FROM INVESTING ACTIVITIES
|
|
|
|
|
|||
|
Capital expenditures of FPL
|
(2,093
|
)
|
(3,061
|
)
|
|||
|
Independent power and other investments of NEER
|
(2,244
|
)
|
(3,025
|
)
|
|||
|
Cash grants under the American Recovery and Reinvestment Act of 2009
|
170
|
|
105
|
|
|||
|
Nuclear fuel purchases
|
(200
|
)
|
(202
|
)
|
|||
|
Other capital expenditures
|
(122
|
)
|
(401
|
)
|
|||
|
Change in loan proceeds restricted for construction
|
245
|
|
212
|
|
|||
|
Proceeds from sale or maturity of securities in special use funds
|
2,604
|
|
3,890
|
|
|||
|
Purchases of securities in special use funds
|
(2,678
|
)
|
(3,994
|
)
|
|||
|
Proceeds from sale or maturity of other securities
|
179
|
|
219
|
|
|||
|
Purchases of other securities
|
(176
|
)
|
(259
|
)
|
|||
|
Other - net
|
49
|
|
15
|
|
|||
|
Net cash used in investing activities
|
(4,266
|
)
|
(6,501
|
)
|
|||
|
CASH FLOWS FROM FINANCING ACTIVITIES
|
|
|
|
|
|||
|
Issuances of long-term debt
|
3,653
|
|
4,226
|
|
|||
|
Retirements of long-term debt
|
(1,669
|
)
|
(1,321
|
)
|
|||
|
Proceeds from sale of differential membership interests
|
201
|
|
414
|
|
|||
|
Payments to differential membership investors
|
(47
|
)
|
(53
|
)
|
|||
|
Net change in short-term debt
|
(495
|
)
|
396
|
|
|||
|
Issuances of common stock - net
|
415
|
|
386
|
|
|||
|
Repurchases of common stock
|
—
|
|
(19
|
)
|
|||
|
Dividends on common stock
|
(836
|
)
|
(752
|
)
|
|||
|
Other - net
|
(117
|
)
|
(64
|
)
|
|||
|
Net cash provided by financing activities
|
1,105
|
|
3,213
|
|
|||
|
Net increase (decrease) in cash and cash equivalents
|
229
|
|
(131
|
)
|
|||
|
Cash and cash equivalents at beginning of period
|
329
|
|
377
|
|
|||
|
Cash and cash equivalents at end of period
|
$
|
558
|
|
$
|
246
|
|
|
|
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
|
|
|
|
|
|||
|
Accrued property additions
|
$
|
792
|
|
$
|
943
|
|
|
|
Sale of hydropower generation plants through assumption of debt by buyer
|
$
|
700
|
|
$
|
—
|
|
|
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the
2012
Form 10-K.
9
FLORIDA POWER & LIGHT COMPANY
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(millions)
(unaudited)
|
|
Three Months Ended September 30,
|
Nine Months Ended September 30,
|
|||||||||||||
|
|
2013
|
2012
|
2013
|
2012
|
|||||||||||
|
OPERATING REVENUES
|
$
|
3,020
|
|
$
|
2,975
|
|
$
|
7,905
|
|
$
|
7,778
|
|
|||
|
OPERATING EXPENSES
|
|
|
|
|
|
|
|
|
|||||||
|
Fuel, purchased power and interchange
|
1,141
|
|
1,280
|
|
2,979
|
|
3,301
|
|
|||||||
|
Other operations and maintenance
|
443
|
|
427
|
|
1,254
|
|
1,305
|
|
|||||||
|
Depreciation and amortization
|
351
|
|
254
|
|
780
|
|
496
|
|
|||||||
|
Taxes other than income taxes and other
|
307
|
|
295
|
|
847
|
|
814
|
|
|||||||
|
Total operating expenses
|
2,242
|
|
2,256
|
|
5,860
|
|
5,916
|
|
|||||||
|
OPERATING INCOME
|
778
|
|
719
|
|
2,045
|
|
1,862
|
|
|||||||
|
OTHER INCOME (DEDUCTIONS)
|
|
|
|
|
|
|
|
|
|||||||
|
Interest expense
|
(105
|
)
|
(104
|
)
|
(310
|
)
|
(314
|
)
|
|||||||
|
Allowance for equity funds used during construction
|
12
|
|
14
|
|
42
|
|
36
|
|
|||||||
|
Other - net
|
—
|
|
—
|
|
1
|
|
—
|
|
|||||||
|
Total other deductions - net
|
(93
|
)
|
(90
|
)
|
(267
|
)
|
(278
|
)
|
|||||||
|
INCOME BEFORE INCOME TAXES
|
685
|
|
629
|
|
1,778
|
|
1,584
|
|
|||||||
|
INCOME TAXES
|
263
|
|
237
|
|
677
|
|
600
|
|
|||||||
|
NET INCOME
(a)
|
$
|
422
|
|
$
|
392
|
|
$
|
1,101
|
|
$
|
984
|
|
|||
__________________________________
|
(a)
|
FPL's comprehensive income is the same as reported net income.
|
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the
2012
Form 10-K.
10
FLORIDA POWER & LIGHT COMPANY
CONDENSED CONSOLIDATED BALANCE SHEETS
(millions, except share amount)
(unaudited)
|
|
September 30,
2013 |
December 31,
2012 |
|||||
|
ELECTRIC UTILITY PLANT
|
|
|
|||||
|
Plant in service and other property
|
$
|
36,472
|
|
$
|
34,474
|
|
|
|
Nuclear fuel
|
1,195
|
|
1,190
|
|
|||
|
Construction work in progress
|
1,718
|
|
2,585
|
|
|||
|
Less accumulated depreciation and amortization
|
(10,885
|
)
|
(10,698
|
)
|
|||
|
Total electric utility plant - net
|
28,500
|
|
27,551
|
|
|||
|
CURRENT ASSETS
|
|
|
|
|
|||
|
Cash and cash equivalents
|
54
|
|
40
|
|
|||
|
Customer receivables, net of allowances of $8 and $7, respectively
|
992
|
|
760
|
|
|||
|
Other receivables
|
152
|
|
447
|
|
|||
|
Materials, supplies and fossil fuel inventory
|
757
|
|
727
|
|
|||
|
Regulatory assets:
|
|
|
|
|
|||
|
Deferred clause and franchise expenses
|
124
|
|
75
|
|
|||
|
Other
|
158
|
|
106
|
|
|||
|
Other
|
151
|
|
131
|
|
|||
|
Total current assets
|
2,388
|
|
2,286
|
|
|||
|
OTHER ASSETS
|
|
|
|
|
|||
|
Special use funds
|
3,155
|
|
2,918
|
|
|||
|
Prepaid benefit costs
|
1,147
|
|
1,135
|
|
|||
|
Regulatory assets:
|
|
|
|
|
|||
|
Securitized storm-recovery costs ($238 and $274 related to a VIE, respectively)
|
388
|
|
461
|
|
|||
|
Other
|
436
|
|
351
|
|
|||
|
Other
|
154
|
|
151
|
|
|||
|
Total other assets
|
5,280
|
|
5,016
|
|
|||
|
TOTAL ASSETS
|
$
|
36,168
|
|
$
|
34,853
|
|
|
|
CAPITALIZATION
|
|
|
|
|
|||
|
Common stock (no par value, 1,000 shares authorized, issued and outstanding)
|
$
|
1,373
|
|
$
|
1,373
|
|
|
|
Additional paid-in capital
|
5,902
|
|
5,903
|
|
|||
|
Retained earnings
|
5,285
|
|
5,254
|
|
|||
|
Total common shareholder's equity
|
12,560
|
|
12,530
|
|
|||
|
Long-term debt ($331 and $386 related to a VIE, respectively)
|
8,474
|
|
8,329
|
|
|||
|
Total capitalization
|
21,034
|
|
20,859
|
|
|||
|
CURRENT LIABILITIES
|
|
|
|
|
|||
|
Commercial paper
|
580
|
|
105
|
|
|||
|
Current maturities of long-term debt
|
355
|
|
453
|
|
|||
|
Accounts payable
|
631
|
|
612
|
|
|||
|
Customer deposits
|
498
|
|
503
|
|
|||
|
Accrued interest and taxes
|
560
|
|
223
|
|
|||
|
Accrued construction-related expenditures
|
144
|
|
235
|
|
|||
|
Other
|
367
|
|
495
|
|
|||
|
Total current liabilities
|
3,135
|
|
2,626
|
|
|||
|
OTHER LIABILITIES AND DEFERRED CREDITS
|
|
|
|
|
|||
|
Asset retirement obligations
|
1,254
|
|
1,206
|
|
|||
|
Deferred income taxes
|
6,133
|
|
5,584
|
|
|||
|
Regulatory liabilities:
|
|
|
|
|
|||
|
Accrued asset removal costs
|
1,784
|
|
1,950
|
|
|||
|
Asset retirement obligation regulatory expense difference
|
1,987
|
|
1,813
|
|
|||
|
Other
|
391
|
|
309
|
|
|||
|
Other
|
450
|
|
506
|
|
|||
|
Total other liabilities and deferred credits
|
11,999
|
|
11,368
|
|
|||
|
COMMITMENTS AND CONTINGENCIES
|
|
|
|
|
|||
|
TOTAL CAPITALIZATION AND LIABILITIES
|
$
|
36,168
|
|
$
|
34,853
|
|
|
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the
2012
Form 10-K.
11
FLORIDA POWER & LIGHT COMPANY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(millions)
(unaudited)
|
|
Nine Months Ended September 30,
|
||||||
|
|
2013
|
2012
|
|||||
|
CASH FLOWS FROM OPERATING ACTIVITIES
|
|
|
|||||
|
Net income
|
$
|
1,101
|
|
$
|
984
|
|
|
|
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
|
|
|
|
|
|||
|
Depreciation and amortization
|
780
|
|
496
|
|
|||
|
Nuclear fuel and other amortization
|
137
|
|
85
|
|
|||
|
Deferred income taxes
|
465
|
|
656
|
|
|||
|
Cost recovery clauses and franchise fees
|
(126
|
)
|
115
|
|
|||
|
Allowance for equity funds used during construction
|
(42
|
)
|
(36
|
)
|
|||
|
Other - net
|
101
|
|
8
|
|
|||
|
Changes in operating assets and liabilities:
|
|
|
|
|
|||
|
Customer and other receivables
|
(265
|
)
|
(289
|
)
|
|||
|
Materials, supplies and fossil fuel inventory
|
(30
|
)
|
24
|
|
|||
|
Other current assets
|
(5
|
)
|
(35
|
)
|
|||
|
Other assets
|
(19
|
)
|
(41
|
)
|
|||
|
Accounts payable
|
93
|
|
60
|
|
|||
|
Income taxes
|
371
|
|
74
|
|
|||
|
Interest and other taxes
|
314
|
|
264
|
|
|||
|
Other current liabilities
|
(65
|
)
|
(55
|
)
|
|||
|
Other liabilities
|
(18
|
)
|
(8
|
)
|
|||
|
Net cash provided by operating activities
|
2,792
|
|
2,302
|
|
|||
|
CASH FLOWS FROM INVESTING ACTIVITIES
|
|
|
|
|
|||
|
Capital expenditures
|
(2,093
|
)
|
(3,061
|
)
|
|||
|
Nuclear fuel purchases
|
(116
|
)
|
(137
|
)
|
|||
|
Proceeds from sale or maturity of securities in special use funds
|
1,967
|
|
2,949
|
|
|||
|
Purchases of securities in special use funds
|
(2,020
|
)
|
(3,031
|
)
|
|||
|
Other - net
|
28
|
|
27
|
|
|||
|
Net cash used in investing activities
|
(2,234
|
)
|
(3,253
|
)
|
|||
|
CASH FLOWS FROM FINANCING ACTIVITIES
|
|
|
|
|
|||
|
Issuances of long-term debt
|
498
|
|
594
|
|
|||
|
Retirements of long-term debt
|
(453
|
)
|
(50
|
)
|
|||
|
Net change in short-term debt
|
475
|
|
142
|
|
|||
|
Capital contribution from NEE
|
—
|
|
240
|
|
|||
|
Dividends to NEE
|
(1,070
|
)
|
—
|
|
|||
|
Other - net
|
6
|
|
9
|
|
|||
|
Net cash provided by (used in) financing activities
|
(544
|
)
|
935
|
|
|||
|
Net increase (decrease) in cash and cash equivalents
|
14
|
|
(16
|
)
|
|||
|
Cash and cash equivalents at beginning of period
|
40
|
|
36
|
|
|||
|
Cash and cash equivalents at end of period
|
$
|
54
|
|
$
|
20
|
|
|
|
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
|
|
|
|
|
|||
|
Accrued property additions
|
$
|
296
|
|
$
|
445
|
|
|
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the
2012
Form 10-K.
12
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(unaudited)
The accompanying condensed consolidated financial statements should be read in conjunction with the 2012 Form 10-K. In the opinion of NEE and FPL management, all adjustments (consisting of normal recurring accruals) considered necessary for fair financial statement presentation have been made. Certain amounts included in the prior year's condensed consolidated financial statements have been reclassified to conform to the current year's presentation. Also, benefits associated with differential membership interests - net have been restated from operating expenses to other income (deductions) to be comparable with the presentation of other financing-related costs. The results of operations for an interim period generally will not give a true indication of results for the year.
1. Employee Retirement Benefits
NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries and has a supplemental executive retirement plan, which includes a non-qualified supplemental defined benefit pension component that provides benefits to a select group of management and highly compensated employees (collectively, pension benefits). In addition to pension benefits, NEE sponsors a contributory postretirement plan for health care and life insurance benefits (other benefits) for retirees of NEE and its subsidiaries meeting certain eligibility requirements.
The components of net periodic benefit (income) cost for the plans are as follows:
|
|
Pension Benefits
|
Other Benefits
|
Pension Benefits
|
Other Benefits
|
||||||||||||||||||||||||||||
|
|
Three Months Ended September 30,
|
Three Months Ended September 30,
|
Nine Months Ended September 30,
|
Nine Months Ended September 30,
|
||||||||||||||||||||||||||||
|
|
2013
|
2012
|
2013
|
2012
|
2013
|
2012
|
2013
|
2012
|
||||||||||||||||||||||||
|
|
(millions)
|
|||||||||||||||||||||||||||||||
|
Service cost
|
$
|
19
|
|
$
|
16
|
|
$
|
1
|
|
$
|
1
|
|
$
|
55
|
|
$
|
49
|
|
$
|
3
|
|
$
|
4
|
|
||||||||
|
Interest cost
|
23
|
|
25
|
|
3
|
|
4
|
|
71
|
|
74
|
|
11
|
|
13
|
|
||||||||||||||||
|
Expected return on plan assets
|
(59
|
)
|
(60
|
)
|
(1
|
)
|
—
|
|
(178
|
)
|
(179
|
)
|
(1
|
)
|
(1
|
)
|
||||||||||||||||
|
Amortization of transition obligation
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
1
|
|
||||||||||||||||
|
Amortization of prior service cost (benefit)
|
2
|
|
1
|
|
—
|
|
(1
|
)
|
6
|
|
3
|
|
(2
|
)
|
—
|
|
||||||||||||||||
|
Amortization of losses
|
—
|
|
—
|
|
1
|
|
—
|
|
1
|
|
—
|
|
2
|
|
—
|
|
||||||||||||||||
|
Special termination benefits
|
15
|
|
—
|
|
—
|
|
—
|
|
27
|
|
—
|
|
—
|
|
—
|
|
||||||||||||||||
|
Net periodic benefit (income) cost at NEE
|
$
|
—
|
|
$
|
(18
|
)
|
$
|
4
|
|
$
|
4
|
|
$
|
(18
|
)
|
$
|
(53
|
)
|
$
|
13
|
|
$
|
17
|
|
||||||||
|
Net periodic benefit (income) cost at FPL
|
$
|
2
|
|
$
|
(11
|
)
|
$
|
3
|
|
$
|
3
|
|
$
|
(10
|
)
|
$
|
(34
|
)
|
$
|
9
|
|
$
|
13
|
|
||||||||
2. Derivative Instruments
NEE and FPL use derivative instruments (primarily swaps, options, futures and forwards) to manage the commodity price risk inherent in the purchase and sale of fuel and electricity, as well as interest rate and foreign currency exchange rate risk associated with outstanding and forecasted debt issuances, and to optimize the value of NEER's power generation and gas infrastructure assets.
With respect to commodities related to NEE's competitive energy business, NEER employs risk management procedures to conduct its activities related to optimizing the value of its power generation and gas infrastructure assets, providing full energy and capacity requirements services primarily to distribution utilities, and engaging in power and gas marketing and trading activities to take advantage of expected future favorable price movements and changes in the expected volatility of prices in the energy markets. These risk management activities involve the use of derivative instruments executed within prescribed limits to manage the risk associated with fluctuating commodity prices. Transactions in derivative instruments are executed on recognized exchanges or via the OTC markets, depending on the most favorable credit terms and market execution factors. For NEER's power generation and gas infrastructure assets, derivative instruments are used to hedge the commodity price risk associated with the fuel requirements of the assets, where applicable, as well as to hedge all or a portion of the expected output of these assets. These hedges are designed to reduce the effect of adverse changes in the wholesale forward commodity markets associated with NEER's power generation and gas infrastructure assets. With regard to full energy and capacity requirements services, NEER is required to vary the quantity of energy and related services it supplies based on the load demands of the customers served. For this type of transaction, derivative instruments are used to hedge the anticipated electricity quantities required to serve these customers and reduce the effect of unfavorable changes in the forward energy markets. Additionally, NEER takes positions in the energy markets based on differences between actual forward market levels and management's view of fundamental market conditions. NEER uses derivative instruments to realize value from these market dislocations, subject to strict risk management limits around market, operational and credit exposure.
13
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Derivative instruments, when required to be marked to market, are recorded on NEE's and FPL's condensed consolidated balance sheets as either an asset or liability measured at fair value. At FPL, substantially all changes in the derivatives' fair value are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the fuel and purchased power cost recovery clause (fuel clause) or the capacity cost recovery clause (capacity clause). For NEE's non-rate regulated operations, predominantly NEER, essentially all changes in the derivatives' fair value for power purchases and sales, fuel sales and trading activities are recognized on a net basis in operating revenues; fuel purchases used in the production of electricity are recognized in fuel, purchased power and interchange expense; and the equity method investees' related activity is recognized in other - net in NEE's condensed consolidated statements of income. Settlement gains and losses are included within the line items in the condensed consolidated statements of income to which they relate. Transactions for which physical delivery is deemed not to have occurred are presented on a net basis in the condensed consolidated statements of income. For commodity derivatives, NEE believes that, where offsetting positions exist at the same location for the same time, the transactions are considered to have been netted and therefore physical delivery has been deemed not to have occurred for financial reporting purposes. Settlements related to derivative instruments are primarily recognized in net cash provided by operating activities in NEE's and FPL's condensed consolidated statements of cash flows.
While most of NEE's derivatives are entered into for the purpose of managing commodity price risk, optimizing the value of NEER's power generation and gas infrastructure assets, reducing the impact of volatility in interest rates on outstanding and forecasted debt issuances and managing foreign currency risk, hedge accounting is only applied where specific criteria are met and it is practicable to do so. In order to apply hedge accounting, the transaction must be designated as a hedge and it must be highly effective in offsetting the hedged risk. Additionally, for hedges of forecasted transactions, the forecasted transactions must be probable. For interest rate and foreign currency derivative instruments, generally NEE assesses a hedging instrument's effectiveness by using nonstatistical methods including dollar value comparisons of the change in the fair value of the derivative to the change in the fair value or cash flows of the hedged item. Hedge effectiveness is tested at the inception of the hedge and on at least a quarterly basis throughout its life. The effective portion of the gain or loss on a derivative instrument designated as a cash flow hedge is reported as a component of other comprehensive income (OCI) and is reclassified into earnings in the period(s) during which the transaction being hedged affects earnings or when it becomes probable that a forecasted transaction being hedged would not occur. The ineffective portion of net unrealized gains (losses) on these hedges is reported in earnings in the current period. In April 2013, NEE discontinued hedge accounting for cash flow hedges related to interest rate swaps associated with the solar projects in Spain (see Note 10 - Spain Solar Projects). At
September 30, 2013
, NEE's accumulated other comprehensive income (AOCI) included amounts related to interest rate cash flow hedges with expiration dates
through June 2031
and foreign currency cash flow hedges with expiration dates
through September 2030
. Approximately
$58 million
of net losses included in AOCI at
September 30, 2013
is expected to be reclassified into earnings within the next 12 months as the principal and/or interest payments are made. Such amounts assume no change in interest rates, currency exchange rates or scheduled principal payments.
The net fair values of NEE's and FPL's mark-to-market derivative instrument assets (liabilities) are included on the condensed consolidated balance sheets as follows:
|
|
NEE
|
FPL
|
|
||||||||||||||
|
|
September 30, 2013
|
December 31, 2012
|
September 30, 2013
|
|
December 31, 2012
|
|
|||||||||||
|
|
(millions)
|
|
|||||||||||||||
|
Current derivative assets
(a)
|
$
|
441
|
|
$
|
517
|
|
$
|
2
|
|
(b)
|
$
|
4
|
|
(b)
|
|||
|
Noncurrent derivative assets
(c)
|
1,011
|
|
920
|
|
—
|
|
1
|
|
(d)
|
||||||||
|
Current derivative liabilities
(e)
|
(615
|
)
|
(430
|
)
|
(55
|
)
|
(f)
|
(20
|
)
|
(f)
|
|||||||
|
Noncurrent derivative liabilities
|
(354
|
)
|
(587
|
)
|
(8
|
)
|
(g)
|
—
|
|
||||||||
|
Total mark-to-market derivative instrument assets (liabilities)
|
$
|
483
|
|
$
|
420
|
|
$
|
(61
|
)
|
$
|
(15
|
)
|
|||||
————————————
|
(a)
|
At
September 30, 2013
and
December 31, 2012
, NEE's balances reflect the netting of approximately
$75 million
and
$43 million
(
none
at FPL), respectively, in margin cash collateral received from counterparties.
|
|
(b)
|
Included in current other assets on FPL's condensed consolidated balance sheets.
|
|
(c)
|
At
September 30, 2013
and
December 31, 2012
, NEE's balances reflect the netting of approximately
$118 million
and
$159 million
(
none
at FPL), respectively, in margin cash collateral received from counterparties.
|
|
(d)
|
Included in noncurrent other assets on FPL's condensed consolidated balance sheets.
|
|
(e)
|
At
September 30, 2013
and
December 31, 2012
, NEE's balances reflect the netting of approximately
$15 million
and
$79 million
(
none
at FPL), respectively, in margin cash collateral provided to counterparties.
|
|
(f)
|
Included in current other liabilities on FPL's condensed consolidated balance sheets.
|
|
(g)
|
Included in noncurrent other liabilities on FPL's condensed consolidated balance sheets.
|
14
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
At
September 30, 2013
and
December 31, 2012
, NEE had approximately
$16 million
and
$30 million
(
none
at FPL), respectively, in margin cash collateral received from counterparties that was not offset against derivative assets in the above presentation. These amounts are included in current other liabilities on NEE's condensed consolidated balance sheets. Additionally, at
September 30, 2013
and
December 31, 2012
, NEE had approximately
$537 million
and
$49 million
(
none
at FPL), respectively, in margin cash collateral provided to counterparties that was not offset against derivative liabilities in the above presentation. These amounts are included in current other assets on NEE's condensed consolidated balance sheets.
As discussed above, NEE uses derivative instruments to, among other things, manage its commodity price risk, interest rate risk and foreign currency exchange rate risk and optimize the value of NEER's power generation and gas infrastructure assets. The table above presents NEE's and FPL's net derivative positions at
September 30, 2013
and
December 31, 2012
, which reflect the offsetting of positions of certain transactions within the portfolio, the contractual ability to settle contracts under master netting arrangements and the netting of margin cash collateral (see Note 3 - Recurring Fair Value Measurements for netting information). However, disclosure rules require that the following tables be presented on a gross basis.
The fair values of NEE's derivatives designated as hedging instruments for accounting purposes (none at FPL) are presented below as gross asset and liability values, as required by disclosure rules.
|
|
September 30, 2013
|
December 31, 2012
|
||||||||||||||
|
|
Derivative
Assets
|
Derivative
Liabilities
|
Derivative
Assets
|
Derivative
Liabilities
|
||||||||||||
|
|
(millions)
|
|||||||||||||||
|
Interest rate contracts:
|
|
|
|
|
||||||||||||
|
Current derivative assets
|
$
|
29
|
|
$
|
—
|
|
$
|
30
|
|
$
|
—
|
|
||||
|
Current derivative liabilities
|
—
|
|
62
|
|
—
|
|
104
|
|
||||||||
|
Noncurrent derivative assets
|
48
|
|
—
|
|
46
|
|
—
|
|
||||||||
|
Noncurrent derivative liabilities
|
—
|
|
68
|
|
—
|
|
283
|
|
||||||||
|
Foreign currency swaps:
|
|
|
|
|
|
|
|
|
||||||||
|
Current derivative liabilities
|
—
|
|
21
|
|
—
|
|
5
|
|
||||||||
|
Noncurrent derivative liabilities
|
—
|
|
16
|
|
—
|
|
28
|
|
||||||||
|
Total
|
$
|
77
|
|
$
|
167
|
|
$
|
76
|
|
$
|
420
|
|
||||
Gains (losses) related to NEE's cash flow hedges are recorded in NEE's condensed consolidated financial statements as follows:
|
|
Three Months Ended September 30,
|
||||||||||||||||||||||||||
|
|
2013
|
2012
|
|||||||||||||||||||||||||
|
|
Interest
Rate
Contracts
|
|
Foreign
Currency
Swaps
|
|
Total
|
Commodity
Contracts
|
|
Interest
Rate
Contracts
|
|
Foreign
Currency
Swap
|
|
Total
|
|||||||||||||||
|
|
(millions)
|
||||||||||||||||||||||||||
|
Gains (losses) recognized in OCI
|
$
|
(29
|
)
|
$
|
4
|
|
|
$
|
(25
|
)
|
$
|
—
|
|
|
$
|
(39
|
)
|
$
|
(6
|
)
|
|
$
|
(45
|
)
|
|||
|
Gains (losses) reclassified from AOCI to net income
(a)
|
$
|
(15
|
)
|
$
|
1
|
|
(b)
|
$
|
(14
|
)
|
$
|
2
|
|
$
|
(14
|
)
|
$
|
2
|
|
(b)
|
$
|
(10
|
)
|
||||
|
(a)
|
Included in operating revenues for commodity contracts and interest expense for interest rate contracts.
|
|
(b)
|
Loss of approximately
$1 million
is included in interest expense and the balance is included in other - net.
|
|
|
Nine Months Ended September 30,
|
||||||||||||||||||||||||||
|
|
2013
|
2012
|
|||||||||||||||||||||||||
|
|
Interest
Rate
Contracts
|
|
Foreign
Currency
Swaps
|
|
Total
|
Commodity
Contracts
|
|
Interest
Rate
Contracts
|
|
Foreign
Currency
Swap
|
|
Total
|
|||||||||||||||
|
|
(millions)
|
||||||||||||||||||||||||||
|
Gains (losses) recognized in OCI
|
$
|
136
|
|
$
|
(8
|
)
|
|
$
|
128
|
|
$
|
—
|
|
|
$
|
(104
|
)
|
$
|
(16
|
)
|
|
$
|
(120
|
)
|
|||
|
Gains (losses) reclassified from AOCI to net income
(a)
|
$
|
(45
|
)
|
$
|
(30
|
)
|
(b)
|
$
|
(75
|
)
|
$
|
6
|
|
$
|
(44
|
)
|
$
|
(4
|
)
|
(c)
|
$
|
(42
|
)
|
||||
|
(a)
|
Included in operating revenues for commodity contracts and interest expense for interest rate contracts.
|
|
(b)
|
Loss of approximately
$3 million
is included in interest expense and the balance is included in other - net.
|
|
(c)
|
Loss of approximately
$2 million
is included in interest expense and the balance is included in other - net.
|
15
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
For the
three and nine months ended September 30, 2013
, NEE recorded a gain of approximately
$2 million
and a loss of
$55 million
, respectively, on fair value hedges which resulted in a corresponding increase and decrease in the related debt, respectively. For the
three and nine months ended September 30, 2012
, NEE recorded a gain of approximately
$6 million
and
$41 million
, respectively, on fair value hedges which resulted in a corresponding increase in the related debt.
The fair values of NEE's and FPL's derivatives not designated as hedging instruments for accounting purposes are presented below as gross asset and liability values, as required by disclosure rules. However, the majority of the underlying contracts are subject to master netting arrangements and would not be contractually settled on a gross basis.
|
September 30, 2013
|
December 31, 2012
|
|||||||||||||||||||||||||||||||
|
NEE
|
FPL
|
NEE
|
FPL
|
|||||||||||||||||||||||||||||
|
Derivative
Assets
|
Derivative
Liabilities
|
Derivative
Assets
|
Derivative
Liabilities
|
Derivative
Assets
|
Derivative
Liabilities
|
Derivative
Assets
|
Derivative
Liabilities
|
|
||||||||||||||||||||||||
|
(millions)
|
||||||||||||||||||||||||||||||||
|
Commodity contracts:
|
||||||||||||||||||||||||||||||||
|
Current derivative assets
|
$
|
689
|
|
$
|
203
|
|
$
|
2
|
|
(a)
|
$
|
—
|
|
$
|
851
|
|
$
|
321
|
|
$
|
4
|
|
(a)
|
$
|
—
|
|
|
|||||
|
Current derivative liabilities
|
1,113
|
|
1,489
|
|
6
|
|
(b)
|
61
|
|
(b)
|
1,441
|
|
1,838
|
|
12
|
|
(b)
|
32
|
|
(b)
|
||||||||||||
|
Noncurrent derivative assets
|
1,798
|
|
717
|
|
—
|
|
|
—
|
|
1,748
|
|
715
|
|
1
|
|
(c)
|
—
|
|
||||||||||||||
|
Noncurrent derivative liabilities
|
235
|
|
505
|
|
1
|
|
(d)
|
9
|
|
(d)
|
192
|
|
438
|
|
—
|
|
|
—
|
|
|||||||||||||
|
Foreign currency swap:
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||||
|
Current derivative liabilities
|
—
|
|
80
|
|
—
|
|
|
—
|
|
|
—
|
|
3
|
|
—
|
|
|
—
|
|
|
||||||||||||
|
Noncurrent derivative liabilities
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
30
|
|
—
|
|
—
|
|
||||||||||||||||
|
Interest rate contracts:
|
||||||||||||||||||||||||||||||||
|
Current derivative assets
|
1
|
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
||||||||||||||||
|
Current derivative liabilities
|
—
|
|
91
|
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
||||||||||||||||
|
Total
|
$
|
3,836
|
|
$
|
3,085
|
|
$
|
9
|
|
|
$
|
70
|
|
|
$
|
4,232
|
|
$
|
3,345
|
|
$
|
17
|
|
|
$
|
32
|
|
|
||||
|
(a)
|
Included in current other assets on FPL's condensed consolidated balance sheets.
|
|
(b)
|
Included in current other liabilities on FPL's condensed consolidated balance sheets.
|
|
(c)
|
Included in noncurrent other assets on FPL's condensed consolidated balance sheets.
|
|
(d)
|
Included in noncurrent other liabilities on FPL's condensed consolidated balance sheets.
|
Gains (losses) related to NEE's derivatives not designated as hedging instruments are recorded in NEE's condensed consolidated statements of income as follows:
|
Three Months Ended September 30,
|
Nine Months Ended September 30,
|
||||||||||||||
|
2013
|
2012
|
2013
|
2012
|
||||||||||||
|
(millions)
|
|||||||||||||||
|
Commodity contracts:
(a)
|
|||||||||||||||
|
Operating revenues
|
$
|
138
|
|
$
|
(218
|
)
|
$
|
111
|
|
$
|
102
|
|
|||
|
Fuel, purchased power and interchange
|
(9
|
)
|
(4
|
)
|
2
|
|
36
|
|
|||||||
|
Foreign currency swap - other - net
|
3
|
|
|
9
|
|
(49
|
)
|
(13
|
)
|
||||||
|
Interest rate contracts - interest expense
|
3
|
|
—
|
|
14
|
|
—
|
|
|||||||
|
Total
|
$
|
135
|
|
$
|
(213
|
)
|
$
|
78
|
|
$
|
125
|
|
|||
————————————
|
(a)
|
For the
three months ended September 30, 2013 and 2012
, FPL recorded approximately
$22 million
of
losses
and
$90 million
of gains, respectively, related to commodity contracts as regulatory assets and regulatory liabilities, respectively, on its condensed consolidated balance sheets. For the
nine months ended September 30, 2013 and 2012
, FPL recorded approximately
$27 million
and
$86 million
of losses, respectively, related to commodity contracts as regulatory assets on its condensed consolidated balance sheets.
|
16
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Notional Volumes of Derivative Instruments
- The following table represents net notional volumes associated with derivative instruments that are required to be reported at fair value in NEE's and FPL's condensed consolidated financial statements. The table includes significant volumes of transactions that have minimal exposure to commodity price changes because they are variably priced agreements. These volumes are only an indication of the commodity exposure that is managed through the use of derivatives. They do not represent net physical asset positions or non-derivative positions and their hedges, nor do they represent NEE
’
s and FPL
’
s net economic exposure, but only the net notional derivative positions that fully or partially hedge the related asset positions. NEE and FPL had derivative commodity contracts for the following net notional volumes:
|
September 30, 2013
|
December 31, 2012
|
|||||||||||||||||||
|
Commodity Type
|
NEE
|
FPL
|
NEE
|
FPL
|
||||||||||||||||
|
(millions)
|
||||||||||||||||||||
|
Power
|
(110
|
)
|
MWh
(a)
|
—
|
|
(77
|
)
|
MWh
(a)
|
—
|
|
||||||||||
|
Natural gas
|
1,174
|
|
MMBtu
(b)
|
705
|
|
MMBtu
(b)
|
1,293
|
|
MMBtu
(b)
|
894
|
|
MMBtu
(b)
|
||||||||
|
Oil
|
(10
|
)
|
barrels
|
—
|
|
(8
|
)
|
barrels
|
—
|
|
||||||||||
————————————
|
(a)
|
Megawatt-hours
|
|
(b)
|
One million British thermal units
|
At
September 30, 2013
and December 31, 2012, NEE had interest rate contracts with a notional amount totaling approximately
$7.6 billion
and
$7.3 billion
, respectively, and foreign currency swaps with a notional amount totaling approximately
$662 million
and
$662 million
, respectively.
Credit
-
Risk
-
Related Contingent
Features
- Certain derivative instruments contain credit-risk-related contingent features including, among other things, the requirement to maintain an investment grade credit rating from specified credit rating agencies and certain financial ratios, as well as credit-related cross-default and material adverse change triggers. At
September 30, 2013
and December 31, 2012, the aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately
$1.7 billion
(
$70 million
for FPL) and
$1.8 billion
(
$32 million
for FPL), respectively.
If the credit-risk-related contingent features underlying these agreements and other commodity-related contracts were triggered, certain subsidiaries of NEE, including FPL, could be required to post collateral or settle contracts according to contractual terms which generally allow netting of contracts in offsetting positions. Certain contracts contain multiple types of credit-related triggers. To the extent these contracts contain a credit ratings downgrade trigger, the maximum exposure is included in the following credit ratings collateral posting requirements. If FPL's and NEECH's credit ratings were downgraded to BBB/Baa2 (a two level downgrade for FPL and a one level downgrade for NEECH from the current lowest applicable rating), applicable NEE subsidiaries would be required to post collateral such that the total posted collateral would be approximately
$300 million
(
$20 million
at FPL) as of
September 30, 2013
and
$400 million
(
$20 million
at FPL) as of December 31, 2012.
If FPL's and NEECH's credit ratings were downgraded to below investment grade, applicable NEE subsidiaries would be required to post additional collateral such that the total posted collateral would be approximately
$2.2 billion
(
$0.5 billion
at FPL) and
$2.3 billion
(
$0.5 billion
at FPL) as of
September 30, 2013
and December 31, 2012, respectively. Some contracts do not contain credit ratings downgrade triggers, but do contain provisions that require certain financial measures be maintained and/or have credit-related cross-default triggers. In the event these provisions were triggered, applicable NEE subsidiaries could be required to post additional collateral of up to approximately
$700 million
(
$150 million
at FPL) and
$700 million
(
$100 million
at FPL) as of
September 30, 2013
and December 31, 2012, respectively.
Collateral related to derivatives may be posted in the form of cash or credit support in the normal course of business. At September 30, 2013, applicable NEE subsidiaries have posted approximately
$29 million
(none at FPL) in cash which could be applied toward the collateral requirements described above. In addition, at
September 30, 2013
and December 31, 2012, applicable NEE subsidiaries have posted approximately
$78 million
(
none
at FPL) and
$150 million
(
none
at FPL), respectively, in the form of letters of credit which could be applied toward the collateral requirements described above. FPL and NEECH have credit facilities generally in excess of the collateral requirements described above that would be available to support, among other things, derivative activities. Under the terms of the credit facilities, maintenance of a specific credit rating is not a condition to drawing on these credit facilities, although there are other conditions to drawing on these credit facilities.
Additionally, some contracts contain certain adequate assurance provisions where a counterparty may demand additional collateral based on subjective events and/or conditions. Due to the subjective nature of these provisions, NEE and FPL are unable to determine an exact value for these items and they are not included in any of the quantitative disclosures above.
17
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
3. Fair Value Measurements
The fair value of assets and liabilities are determined using either unadjusted quoted prices in active markets (Level 1) or pricing inputs that are observable (Level 2) whenever that information is available and using unobservable inputs (Level 3) to estimate fair value only when relevant observable inputs are not available. NEE and FPL use several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those assets and liabilities that are measured at fair value on a recurring basis. NEE's and FPL's assessment of the significance of any particular input to the fair value measurement requires judgment and may affect their placement within the fair value hierarchy levels. Non-performance risk, including the consideration of a credit valuation adjustment, is also considered in the determination of fair value for all assets and liabilities measured at fair value.
Cash Equivalents
- Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less. NEE and FPL primarily hold investments in money market funds. The fair value of these funds is calculated using current market prices.
Special Use Funds and Other Investments
- NEE and FPL hold primarily debt and equity securities directly, as well as indirectly through commingled funds. Substantially all directly held equity securities are valued at their quoted market prices. For directly held debt securities, multiple prices and price types are obtained from pricing vendors whenever possible, which enables cross-provider validations. A primary price source is identified based on asset type, class or issue of each security. Commingled funds, which are similar to mutual funds, are maintained by banks or investment companies and hold certain investments in accordance with a stated set of objectives. The fair value of commingled funds is primarily derived from the quoted prices in active markets of the underlying securities. Because the fund shares are offered to a limited group of investors, they are not considered to be traded in an active market.
Derivative Instruments
- NEE and FPL measure the fair value of commodity contracts using prices observed on commodities exchanges and in the OTC markets, or through the use of industry-standard valuation techniques, such as option modeling or discounted cash flows techniques, incorporating both observable and unobservable valuation inputs. The resulting measurements are the best estimate of fair value as represented by the transfer of the asset or liability through an orderly transaction in the marketplace at the measurement date.
Most exchange-traded derivative assets and liabilities are valued directly using unadjusted quoted prices. For exchange-traded derivative assets and liabilities where the principal market is deemed to be inactive based on average daily volumes and open interest, the measurement is established using settlement prices from the exchanges, and therefore considered to be valued using other observable inputs.
NEE, through its subsidiaries, including FPL, also enters into OTC commodity contract derivatives. The majority of these contracts are transacted at liquid trading points, and the prices for these contracts are verified using quoted prices in active markets from exchanges, brokers or pricing services for similar contracts.
NEE, through NEER, also enters into full requirements contracts, which, in most cases, meet the definition of derivatives and are measured at fair value. These contracts typically have one or more inputs that are not observable and are significant to the valuation of the contract. In addition, certain exchange and non-exchange traded derivative options at NEE have one or more significant inputs that are not observable, and are valued using industry-standard option models.
In all cases where NEE and FPL use significant unobservable inputs for the valuation of a commodity contract, consideration is given to the assumptions that market participants would use in valuing the asset or liability. The primary input to the valuation models for commodity contracts is the forward commodity curve for the respective instruments. Other inputs include, but are not limited to, assumptions about market liquidity, volatility, correlation and contract duration as more fully described below in Significant Unobservable Inputs Used in Recurring Fair Value Measurements. In instances where the reference markets are deemed to be inactive or do not have transactions for a similar contract, the derivative assets and liabilities may be valued using significant other observable inputs and potentially significant unobservable inputs.
In such instances, the valuation for these contracts is established using techniques including extrapolation from or interpolation between actively traded contracts, or estimated basis adjustments from liquid trading points. NEE and FPL regularly evaluate and validate the inputs used to determine fair value by a number of methods, consisting of various market price verification procedures, including the use of pricing services and multiple broker quotes to support the market price of the various commodities. In all cases where there are assumptions and models used to generate inputs for valuing derivative assets and liabilities, the review and verification of the assumptions, models and changes to the models are undertaken by individuals that are independent of those responsible for estimating fair value.
18
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
NEE uses interest rate contracts and foreign currency swaps to mitigate and adjust interest rate and foreign currency exposure related to certain outstanding and forecasted debt issuances and borrowings when deemed appropriate based on market conditions or when required by financing agreements. NEE estimates the fair value of these derivatives using a discounted cash flows valuation technique based on the net amount of estimated future cash inflows and outflows related to the agreements.
Recurring Fair Value Measurements -
NEE's and FPL's financial assets and liabilities and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows:
|
|
September 30, 2013
|
|
||||||||||||||||||
|
|
Quoted Prices in
Active Markets for
Identical Assets
or Liabilities
(Level 1)
|
Significant
Other
Observable
Inputs
(Level 2)
|
|
Significant
Unobservable
Inputs
(Level 3)
|
Netting
(a)
|
Total
|
|
|||||||||||||
|
|
(millions)
|
|
||||||||||||||||||
|
Assets:
|
|
|
|
|
|
|
|
|||||||||||||
|
Cash equivalents:
|
|
|
|
|
|
|
|
|||||||||||||
|
NEE - equity securities
|
$
|
109
|
|
$
|
—
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
109
|
|
|
|||
|
FPL - equity securities
|
$
|
4
|
|
$
|
—
|
|
$
|
—
|
|
$
|
—
|
|
$
|
4
|
|
|||||
|
Special use funds:
|
|
|
|
|
|
|
|
|||||||||||||
|
NEE:
|
|
|
|
|
|
|
|
|||||||||||||
|
Equity securities
|
$
|
1,041
|
|
$
|
1,475
|
|
(b)
|
$
|
—
|
|
$
|
—
|
|
$
|
2,516
|
|
|
|||
|
U.S. Government and municipal bonds
|
$
|
491
|
|
$
|
156
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
647
|
|
|
|||
|
Corporate debt securities
|
$
|
—
|
|
$
|
560
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
560
|
|
|
|||
|
Mortgage-backed securities
|
$
|
—
|
|
$
|
510
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
510
|
|
|
|||
|
Other debt securities
|
$
|
19
|
|
$
|
42
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
61
|
|
|
|||
|
FPL:
|
|
|
|
|
|
|
|
|||||||||||||
|
Equity securities
|
$
|
217
|
|
$
|
1,330
|
|
(b)
|
$
|
—
|
|
$
|
—
|
|
$
|
1,547
|
|
|
|||
|
U.S. Government and municipal bonds
|
$
|
429
|
|
$
|
131
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
560
|
|
|
|||
|
Corporate debt securities
|
$
|
—
|
|
$
|
397
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
397
|
|
|
|||
|
Mortgage-backed securities
|
$
|
—
|
|
$
|
429
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
429
|
|
|
|||
|
Other debt securities
|
$
|
18
|
|
$
|
28
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
46
|
|
|
|||
|
Other investments:
|
|
|
|
|
|
|
|
|||||||||||||
|
NEE:
|
|
|
|
|
|
|
|
|||||||||||||
|
Equity securities
|
$
|
45
|
|
$
|
—
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
45
|
|
|
|||
|
U.S. Government and municipal bonds
|
$
|
11
|
|
$
|
10
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
21
|
|
|
|||
|
Corporate debt securities
|
$
|
—
|
|
$
|
56
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
56
|
|
|
|||
|
Mortgage-backed securities
|
$
|
—
|
|
$
|
38
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
38
|
|
|
|||
|
Other
|
$
|
5
|
|
$
|
5
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
10
|
|
|
|||
|
Derivatives:
|
|
|
|
|
|
|
|
|||||||||||||
|
NEE:
|
|
|
|
|
|
|
|
|||||||||||||
|
Commodity contracts
|
$
|
1,054
|
|
$
|
1,844
|
|
|
$
|
937
|
|
$
|
(2,461
|
)
|
$
|
1,374
|
|
(c)
|
|||
|
Interest rate contracts
|
$
|
—
|
|
$
|
78
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
78
|
|
(c)
|
|||
|
FPL - commodity contracts
|
$
|
—
|
|
$
|
7
|
|
|
$
|
2
|
|
$
|
(7
|
)
|
$
|
2
|
|
(c)
|
|||
|
Liabilities:
|
|
|
|
|
|
|
|
|||||||||||||
|
Derivatives:
|
|
|
|
|
|
|
|
|||||||||||||
|
NEE:
|
|
|
|
|
|
|
|
|||||||||||||
|
Commodity contracts
|
$
|
1,027
|
|
$
|
1,665
|
|
|
$
|
222
|
|
$
|
(2,283
|
)
|
$
|
631
|
|
(c)
|
|||
|
Interest rate contracts
|
$
|
—
|
|
$
|
130
|
|
|
$
|
91
|
|
$
|
—
|
|
$
|
221
|
|
(c)
|
|||
|
Foreign currency swaps
|
$
|
—
|
|
$
|
117
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
117
|
|
(c)
|
|||
|
FPL - commodity contracts
|
$
|
—
|
|
$
|
69
|
|
|
$
|
1
|
|
$
|
(7
|
)
|
$
|
63
|
|
(c)
|
|||
|
(a)
|
Includes the effect of the contractual ability to settle contracts under master netting arrangements and margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the condensed consolidated balance sheets and are recorded in customer receivables - net and accounts payable, respectively.
|
|
(b)
|
At NEE, approximately
$1,461 million
(
$1,317 million
at FPL) are invested in commingled funds whose underlying investments would be Level 1 if those investments were held directly by NEE or FPL.
|
|
(c)
|
See Note 2 for a reconciliation of net derivatives to NEE's and FPL's condensed consolidated balance sheets.
|
19
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
|
|
December 31, 2012
|
|
||||||||||||||||||
|
|
Quoted Prices in
Active Markets for
Identical Assets
or Liabilities
(Level 1)
|
Significant
Other
Observable
Inputs
(Level 2)
|
|
Significant
Unobservable
Inputs
(Level 3)
|
Netting
(a)
|
Total
|
|
|||||||||||||
|
|
(millions)
|
|
||||||||||||||||||
|
Assets:
|
|
|
|
|
|
|
|
|||||||||||||
|
Cash equivalents:
|
|
|
|
|
|
|
|
|||||||||||||
|
NEE - equity securities
|
$
|
23
|
|
$
|
—
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
23
|
|
|
|||
|
FPL - equity securities
|
$
|
5
|
|
$
|
—
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
5
|
|
|
|||
|
Special use funds:
|
|
|
|
|
|
|
|
|||||||||||||
|
NEE:
|
|
|
|
|
|
|
|
|||||||||||||
|
Equity securities
|
$
|
914
|
|
$
|
1,240
|
|
(b)
|
$
|
—
|
|
$
|
—
|
|
$
|
2,154
|
|
|
|||
|
U.S. Government and municipal bonds
|
$
|
451
|
|
$
|
143
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
594
|
|
|
|||
|
Corporate debt securities
|
$
|
—
|
|
$
|
572
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
572
|
|
|
|||
|
Mortgage-backed securities
|
$
|
—
|
|
$
|
560
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
560
|
|
|
|||
|
Other debt securities
|
$
|
15
|
|
$
|
26
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
41
|
|
|
|||
|
FPL:
|
|
|
|
|
|
|
|
|||||||||||||
|
Equity securities
|
$
|
217
|
|
$
|
1,118
|
|
(b)
|
$
|
—
|
|
$
|
—
|
|
$
|
1,335
|
|
|
|||
|
U.S. Government and municipal bonds
|
$
|
390
|
|
$
|
119
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
509
|
|
|
|||
|
Corporate debt securities
|
$
|
—
|
|
$
|
397
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
397
|
|
|
|||
|
Mortgage-backed securities
|
$
|
—
|
|
$
|
475
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
475
|
|
|
|||
|
Other debt securities
|
$
|
16
|
|
$
|
16
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
32
|
|
|
|||
|
Other investments:
|
|
|
|
|
|
|
|
|||||||||||||
|
NEE:
|
|
|
|
|
|
|
|
|||||||||||||
|
Equity securities
|
$
|
7
|
|
$
|
—
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
7
|
|
|
|||
|
U.S. Government and municipal bonds
|
$
|
6
|
|
$
|
—
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
6
|
|
|
|||
|
Corporate debt securities
|
$
|
—
|
|
$
|
53
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
53
|
|
|
|||
|
Mortgage-backed securities
|
$
|
—
|
|
$
|
47
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
47
|
|
|
|||
|
Other
|
$
|
5
|
|
$
|
6
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
11
|
|
|
|||
|
Derivatives:
|
|
|
|
|
|
|
|
|||||||||||||
|
NEE:
|
|
|
|
|
|
|
|
|||||||||||||
|
Commodity contracts
|
$
|
1,187
|
|
$
|
2,251
|
|
|
$
|
794
|
|
$
|
(2,871
|
)
|
$
|
1,361
|
|
(c)
|
|||
|
Interest rate contracts
|
$
|
—
|
|
$
|
76
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
76
|
|
(c)
|
|||
|
FPL - commodity contracts
|
$
|
—
|
|
$
|
14
|
|
|
$
|
3
|
|
$
|
(12
|
)
|
$
|
5
|
|
(c)
|
|||
|
Liabilities:
|
|
|
|
|
|
|
|
|||||||||||||
|
Derivatives:
|
|
|
|
|
|
|
|
|||||||||||||
|
NEE:
|
|
|
|
|
|
|
|
|||||||||||||
|
Commodity contracts
|
$
|
1,240
|
|
$
|
1,844
|
|
|
$
|
228
|
|
$
|
(2,748
|
)
|
$
|
564
|
|
(c)
|
|||
|
Interest rate contracts
|
$
|
—
|
|
$
|
387
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
387
|
|
(c)
|
|||
|
Foreign currency swaps
|
$
|
—
|
|
$
|
66
|
|
|
$
|
—
|
|
$
|
—
|
|
$
|
66
|
|
(c)
|
|||
|
FPL - commodity contracts
|
$
|
—
|
|
$
|
31
|
|
|
$
|
1
|
|
$
|
(12
|
)
|
$
|
20
|
|
(c)
|
|||
|
(a)
|
Includes the effect of the contractual ability to settle contracts under master netting arrangements and margin cash collateral payments and receipts. NEE and FPL also have contract settlement receivable and payable balances that are subject to the master netting arrangements but are not offset within the condensed consolidated balance sheets and are recorded in customer receivables - net and accounts payable, respectively.
|
|
(b)
|
At NEE, approximately
$1,214 million
(
$1,093 million
at FPL) are invested in commingled funds whose underlying investments would be Level 1 if those investments were held directly by NEE or FPL.
|
|
(c)
|
See Note 2 for a reconciliation of net derivatives to NEE's and FPL's condensed consolidated balance sheets.
|
20
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Significant Unobservable Inputs Used in Recurring Fair Value Measurements
- The valuation of certain commodity contracts requires the use of significant unobservable inputs. All forward price, implied volatility, implied correlation and interest rate inputs used in the valuation of such contracts are directly based on third-party market data, such as broker quotes and exchange settlements, when that data is available. If third-party market data is not available, then industry standard methodologies are used to develop inputs that maximize the use of relevant observable inputs and minimize the use of unobservable inputs. Observable inputs, including some forward prices, implied volatilities and interest rates used for determining fair value are updated daily to reflect the best available market information. Unobservable inputs which are related to observable inputs, such as illiquid portions of forward price or volatility curves, are updated daily as well, using industry standard techniques such as interpolation and extrapolation, combining observable forward inputs supplemented by historical market and other relevant data. Other unobservable inputs, such as implied correlations, customer migration rates from full requirements contracts and some implied volatility curves, are modeled using proprietary models based on historical data and industry standard techniques.
All price, volatility, correlation and customer migration inputs used in valuation are subject to validation by the Risk Management group. The Risk Management group performs a risk management function responsible for assessing credit, market and operational risk impact, reviewing valuation methodology and modeling, confirming transactions, monitoring approval processes and developing and monitoring trading limits. The Risk Management group is separate from the transacting group, and the Vice President of Risk Management reports to the Chief Financial Officer of NEE and FPL. For markets where independent third-party data is readily available, validation is conducted daily by directly reviewing this market data against inputs utilized by the transacting group, and indirectly by critically reviewing daily risk reports. For markets where independent third-party data is not readily available, additional analytical reviews are performed on at least a quarterly basis. These analytical reviews are designed to ensure that all price and volatility curves used for fair valuing transactions are adequately validated each quarter, and are reviewed and approved by the Vice President of Risk Management. In addition, other valuation assumptions such as implied correlations and customer migration rates are reviewed and approved by the Risk Management group on a periodic basis. Newly created models used in the valuation process are also subject to testing and approval by the Risk Management group prior to use and established models are reviewed annually, or more often as needed, by the Risk Management group.
On a monthly basis, the Exposure Management Committee (EMC), which is comprised of certain members of senior management, meets with representatives from the Risk Management group and the transacting group to discuss NEE's and FPL's energy risk profile and operations, to review risk reports and to discuss fair value issues as necessary. The EMC develops guidelines required for an appropriate risk management control infrastructure, which includes implementation and monitoring of compliance with Risk Management policy. The EMC executes its risk management responsibilities through direct oversight and delegation of its responsibilities to the Vice President of Risk Management, as well as to other corporate and business unit personnel.
The significant unobservable inputs used in the valuation of NEE's commodity contracts categorized as Level 3 of the fair value hierarchy at
September 30, 2013
are as follows:
|
Transaction Type
|
Fair Value at
September 30, 2013
|
Valuation
Technique(s)
|
Significant
Unobservable Inputs
|
Range
|
||||||||||||
|
Assets
|
Liabilities
|
|||||||||||||||
|
(millions)
|
||||||||||||||||
|
Forward contracts - power
|
$
|
507
|
|
$
|
67
|
|
Discounted cash flow
|
Forward price (per MWh)
|
$10
|
—
|
$205
|
|||||
|
Forward contracts - gas
|
53
|
|
12
|
|
Discounted cash flow
|
Forward price (per MMBtu)
|
$2
|
—
|
$4
|
|||||||
|
Forward contracts - other commodity related
|
12
|
|
14
|
|
Discounted cash flow
|
Forward price (various)
|
$1
|
—
|
$245
|
|||||||
|
Options - power
|
106
|
|
63
|
|
Option models
|
Implied correlations
|
7%
|
—
|
96%
|
|||||||
|
Implied volatilities
|
1%
|
—
|
111%
|
|||||||||||||
|
Options - gas
|
25
|
|
16
|
|
Option models
|
Implied correlations
|
7%
|
—
|
96%
|
|||||||
|
Implied volatilities
|
1%
|
—
|
36%
|
|||||||||||||
|
Full requirements and unit contingent contracts
|
234
|
|
50
|
|
Discounted cash flow
|
Forward price (per MWh)
|
$(32)
|
—
|
$136
|
|||||||
|
Customer migration rate
(a)
|
—%
|
—
|
20%
|
|||||||||||||
|
Total
|
$
|
937
|
|
$
|
222
|
|
||||||||||
——————————
|
(a)
|
Applies only to full requirements contracts.
|
21
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
The sensitivity of NEE's fair value measurements to increases (decreases) in the significant unobservable inputs is as follows:
|
Significant Unobservable Input
|
Position
|
Impact on
Fair Value Measurement
|
||
|
Forward price
|
Purchase power/gas
|
Increase (decrease)
|
||
|
Sell power/gas
|
Decrease (increase)
|
|||
|
Implied correlations
|
Purchase option
|
Decrease (increase)
|
||
|
Sell option
|
Increase (decrease)
|
|||
|
Implied volatilities
|
Purchase option
|
Increase (decrease)
|
||
|
Sell option
|
Decrease (increase)
|
|||
|
Customer migration rate
|
Sell power
(a)
|
Decrease (increase)
|
||
————————————
(a) Assumes the contract is in a gain position.
In addition, the fair value measurement of interest rate swap liabilities related to the solar projects in Spain of approximately
$91 million
at
September 30, 2013
includes a significant credit valuation adjustment. The credit valuation adjustment, considered an unobservable input, reflects management's assessment of non-performance risk of the subsidiaries related to the solar projects in Spain that are party to the swap agreements.
The reconciliation of changes in the fair value of derivatives that are based on significant unobservable inputs is as follows:
|
|
Three Months Ended September 30,
|
||||||||||||||
|
2013
|
2012
|
||||||||||||||
|
|
NEE
|
FPL
|
NEE
|
FPL
|
|||||||||||
|
|
(millions)
|
||||||||||||||
|
Fair value of net derivatives based on significant unobservable inputs at June 30
|
$
|
384
|
|
$
|
(1
|
)
|
$
|
575
|
|
$
|
7
|
|
|||
|
Realized and unrealized gains (losses):
|
|
|
|
|
|
|
|
|
|||||||
|
Included in earnings
(a)
|
243
|
|
—
|
|
(149
|
)
|
—
|
|
|||||||
|
Included in regulatory assets and liabilities
|
2
|
|
2
|
|
1
|
|
1
|
|
|||||||
|
Purchases
|
19
|
|
—
|
|
40
|
|
—
|
|
|||||||
|
Settlements
|
(3
|
)
|
—
|
|
30
|
|
(3
|
)
|
|||||||
|
Issuances
|
(16
|
)
|
—
|
|
(21
|
)
|
—
|
|
|||||||
|
Transfers in
(b)
|
(2
|
)
|
—
|
|
5
|
|
—
|
|
|||||||
|
Transfers out
(b)
|
(3
|
)
|
—
|
|
1
|
|
—
|
|
|||||||
|
Fair value of net derivatives based on significant unobservable inputs at September 30
|
$
|
624
|
|
$
|
1
|
|
$
|
482
|
|
$
|
5
|
|
|||
|
The amount of gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to derivatives still held at the reporting date
(c)
|
$
|
188
|
|
$
|
—
|
|
$
|
(171
|
)
|
$
|
—
|
|
|||
|
(a)
|
For the
three months ended September 30, 2013
, realized and unrealized gains of approximately
$242 million
are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange. For the
three months ended September 30, 2012
, realized and unrealized losses of approximately
$149 million
are reflected in the condensed consolidated statements of income in operating revenues.
|
|
(b)
|
Transfers into Level 3 were a result of decreased observability of market data. Transfers from Level 3 to Level 2 were a result of increased observability of market data. NEE's and FPL's policy is to recognize all transfers at the beginning of the reporting period.
|
|
(c)
|
For the
three months ended September 30, 2013
, unrealized gains of
$188 million
are reflected in the condensed consolidated statements of income in operating revenues. For the
three months ended September 30, 2012
, unrealized losses of approximately
$170 million
are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.
|
22
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
|
|
Nine Months Ended September 30,
|
||||||||||||||
|
2013
|
2012
|
||||||||||||||
|
|
NEE
|
FPL
|
NEE
|
FPL
|
|||||||||||
|
|
(millions)
|
||||||||||||||
|
Fair value of net derivatives based on significant unobservable inputs at December 31 of prior year
|
$
|
566
|
|
$
|
2
|
|
$
|
486
|
|
$
|
4
|
|
|||
|
Realized and unrealized gains (losses):
|
|||||||||||||||
|
Included in earnings
(a)
|
253
|
|
—
|
|
135
|
|
—
|
|
|||||||
|
Included in regulatory assets and liabilities
|
—
|
|
—
|
|
7
|
|
7
|
|
|||||||
|
Purchases
|
89
|
|
—
|
|
221
|
|
—
|
|
|||||||
|
Settlements
|
(59
|
)
|
(1
|
)
|
(152
|
)
|
(6
|
)
|
|||||||
|
Issuances
|
(110
|
)
|
—
|
|
(221
|
)
|
—
|
|
|||||||
|
Transfers in
(b)
|
(116
|
)
|
—
|
|
21
|
|
—
|
|
|||||||
|
Transfers out
(b)
|
1
|
|
—
|
|
(15
|
)
|
—
|
|
|||||||
|
Fair value of net derivatives based on significant unobservable inputs at September 30
|
$
|
624
|
|
$
|
1
|
|
$
|
482
|
|
$
|
5
|
|
|||
|
The amount of gains for the period included in earnings attributable to the change in unrealized gains (losses) relating to derivatives still held at the reporting date
(c)
|
$
|
256
|
|
$
|
—
|
|
$
|
41
|
|
$
|
—
|
|
|||
|
(a)
|
For the
nine months ended September 30, 2013
, realized and unrealized gains (losses) of approximately
$244 million
are reflected in the condensed consolidated statements of income in operating revenues,
$11 million
in interest expense and the balance is reflected in fuel, purchased power and interchange. For the
nine months ended September 30, 2012
, realized and unrealized gains of approximately
$132 million
are reflected in the condensed consolidated statements of income in operating revenues and the balance is reflected in fuel, purchased power and interchange.
|
|
(b)
|
Transfers into Level 3 were a result of decreased observability of market data and, in 2013, the use of a significant credit valuation adjustment. Transfers from Level 3 to Level 2 were a result of increased observability of market data. NEE's and FPL's policy is to recognize all transfers at the beginning of the reporting period.
|
|
(c)
|
For the
nine months ended September 30, 2013
, unrealized gains of approximately
$245 million
are reflected in the condensed consolidated statements of income in operating revenues and
$11 million
in interest expense. For the
nine months ended September 30, 2012
, unrealized gains of approximately
$41 million
are reflected in the condensed consolidated statements of income in operating revenues.
|
Nonrecurring Fair Value Measurements -
NEE tests long-lived assets for recoverability whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. In February 2013, the Spanish government enacted a new law that made further changes to the economic framework of renewable energy projects including, among other things, changes that negatively affect the projected economics of the
99.8
megawatts (MW) of solar thermal facilities that affiliates of NEER were constructing in Spain (Spain solar projects) (see Note 10 - Spain Solar Projects). Due to the February 2013 change in law, NEER performed a recoverability analysis, considering, among other things, working with lenders to restructure the financing agreements, abandoning the projects or selling the projects, and concluded that the undiscounted cash flows of the Spain solar projects were less than the carrying value of the projects. Accordingly, NEER performed a fair value analysis based on the income approach to determine the amount of the impairment. Based on the fair value analysis, property, plant and equipment with a carrying amount of approximately
$800
million were written down to their estimated fair value of approximately
$500
million as of March 31, 2013, resulting in an impairment charge of
$300
million (
$342
million after-tax, see Note 5), which is recorded as a separate line item in NEE’s condensed consolidated statements of income for the
nine months ended September 30, 2013
.
The estimate of the fair value was based on the discounted cash flows which were determined using a market participant view of the Spain solar projects upon completion and final commissioning of the projects. As part of the valuation, NEER used observable inputs where available, including the revised renewable energy pricing under the February 2013 change in law. Significant unobservable inputs (Level 3), including forecasts of generation, estimates of tariff escalation rates and estimated costs of debt and equity capital, were also used in the estimation of fair value. In addition, NEER made certain assumptions regarding the projected capital and maintenance expenditures based on the estimated costs to complete the Spain solar projects and ongoing capital and maintenance expenditures. An increase in the revenue and generation forecasts, a decrease in the projected capital and maintenance expenditures or a decrease in the weighted average cost of capital each would result in an increased fair market value. Changes in the opposite direction of those unobservable inputs would result in a decreased fair market value. See Note 10 - Spain Solar Projects for a discussion of additional developments that could potentially impact the Spain solar projects.
See Note 6 for a discussion of the nonrecurring fair value measurement of certain discontinued operations.
23
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
4. Financial Instruments
The carrying amounts of cash equivalents, short-term debt and commercial paper approximate their fair values. At
September 30, 2013
and
December 31, 2012
, other investments of NEE, not included in the table below, included financial instruments of approximately
$35 million
and
$41 million
, respectively, which primarily consist of notes receivable that are carried at estimated fair value or cost, which approximates fair value.
The following estimates of the fair value of financial instruments have been made primarily using the market approach of using prices and other market information for identical and/or comparable assets and liabilities. However, the use of different market assumptions or methods of valuation could result in different estimated fair values.
|
|
September 30, 2013
|
|
December 31, 2012
|
|
||||||||||||
|
|
Carrying
Amount
|
|
Estimated
Fair Value
|
|
Carrying
Amount
|
|
Estimated
Fair Value
|
|
||||||||
|
|
(millions)
|
|
||||||||||||||
|
NEE:
|
|
|
||||||||||||||
|
Special use funds
|
$
|
4,574
|
|
(a)
|
$
|
4,574
|
|
(a)
|
$
|
4,190
|
|
(a)
|
$
|
4,190
|
|
(a)
|
|
Other investments:
|
|
|
|
|
|
|
|
|
||||||||
|
Notes receivable
|
$
|
500
|
|
|
$
|
624
|
|
(b)
|
$
|
500
|
|
|
$
|
665
|
|
(b)
|
|
Debt securities
|
$
|
121
|
|
(c)
|
$
|
121
|
|
(d)
|
$
|
111
|
|
(c)
|
$
|
111
|
|
(d)
|
|
Equity securities
|
$
|
49
|
|
|
$
|
49
|
|
(e)
|
$
|
61
|
|
|
$
|
79
|
|
(e)
|
|
Long-term debt, including current maturities
|
$
|
27,788
|
|
$
|
28,744
|
|
(f)
|
$
|
26,647
|
|
(g)
|
$
|
28,874
|
|
(f)
|
|
|
Interest rate contracts - net unrealized losses
|
$
|
(143
|
)
|
|
$
|
(143
|
)
|
(d)
|
$
|
(311
|
)
|
$
|
(311
|
)
|
(d)
|
|
|
Foreign currency swaps - net unrealized losses
|
$
|
(117
|
)
|
|
$
|
(117
|
)
|
(d)
|
$
|
(66
|
)
|
|
$
|
(66
|
)
|
(d)
|
|
FPL:
|
|
|
|
|
|
|
|
|
||||||||
|
Special use funds
|
$
|
3,155
|
|
(a)
|
$
|
3,155
|
|
(a)
|
$
|
2,918
|
|
(a)
|
$
|
2,918
|
|
(a)
|
|
Long-term debt, including current maturities
|
$
|
8,829
|
|
|
$
|
9,634
|
|
(f)
|
$
|
8,782
|
|
|
$
|
10,421
|
|
(f)
|
————————————
|
(a)
|
At
September 30, 2013
, includes
$234 million
of investments accounted for under the equity method and
$46 million
of loans not measured at fair value on a recurring basis (
$143 million
and
$33 million
, respectively, for FPL). At
December 31, 2012
, includes
$229 million
of investments accounted for under the equity method and
$40 million
of loans not measured at fair value on a recurring basis (
$138 million
and
$32 million
, respectively, for FPL). For the remaining balances, see Note 3 for classification by major security type and hierarchy level. The amortized cost of debt and equity securities is
$1,758 million
and
$1,488 million
, respectively, at
September 30, 2013
and
$1,679 million
and
$1,500 million
, respectively, at
December 31, 2012
(
$1,411 million
and
$788 million
, respectively, at
September 30, 2013
and
$1,339 million
and
$839 million
, respectively, at
December 31, 2012
for FPL).
|
|
(b)
|
Classified as held to maturity. Estimated using a discounted cash flow valuation technique based on certain observable yield curves and indices considering the credit profile of the borrower (Level 3). Notes receivable bear interest at fixed rates and mature by
2029
. Notes receivable are considered impaired and placed in non-accrual status when it becomes probable that all amounts due cannot be collected in accordance with the contractual terms of the agreement. The assessment to place notes receivable in non-accrual status considers various credit indicators, such as credit ratings and market-related information. As of
September 30, 2013
and December 31, 2012, NEE had no notes receivable reported in non-accrual status.
|
|
(c)
|
Classified as trading securities.
|
|
(d)
|
See Note 3.
|
|
(e)
|
Primarily based on quoted prices in active markets (Level 1). The remainder is modeled internally based on recent market information including, among other things, private offerings of the securities (Level 3).
|
|
(f)
|
As of
September 30, 2013
and
December 31, 2012
,
$18,262 million
and
$18,962 million
, respectively, is estimated using quoted market prices for the same or similar issues (Level 2); the balance is estimated using a discounted cash flow valuation technique, considering the current credit spread of the debtor (Level 3). For FPL, estimated using quoted market prices for the same or similar issues (Level 2).
|
|
(g)
|
Also includes long-term debt reflected in liabilities associated with assets held for sale on the condensed consolidated balance sheets, for which the carrying amount approximates fair value.
|
Special Use Funds
- The special use funds consist of FPL's storm fund assets of
$74 million
and NEE's and FPL's nuclear decommissioning fund assets of
$4,500 million
and
$3,081 million
, respectively, at
September 30, 2013
. The investments held in the special use funds consist of equity and debt securities which are primarily classified as available for sale and carried at estimated fair value (see Note 3). For FPL's special use funds, consistent with regulatory treatment, changes in fair value, including any other than temporary impairment losses, result in a corresponding adjustment to the related regulatory liability accounts. For NEE's non-rate regulated operations, changes in fair value result in a corresponding adjustment to OCI, except for unrealized losses associated with marketable securities considered to be other than temporary, including any credit losses, which are recognized as other than temporary impairment losses on securities held in nuclear decommissioning funds and included in other - net in NEE's condensed consolidated statements of income. Debt securities included in the nuclear decommissioning funds have a weighted-average maturity at
September 30, 2013
of approximately
seven
years at both NEE and FPL. FPL's storm fund primarily consists of debt securities with a weighted-average maturity at
September 30, 2013
of approximately
three
years. The cost of securities sold is determined using the specific identification method.
24
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Realized gains and losses and proceeds from the sale or maturity of available for sale securities are as follows:
|
|
NEE
|
FPL
|
NEE
|
FPL
|
|||||||||||||||||||||||||||
|
|
Three Months Ended September 30,
|
Three Months Ended September 30,
|
Nine Months Ended September 30,
|
Nine Months Ended September 30,
|
|||||||||||||||||||||||||||
|
|
2013
|
2012
|
2013
|
2012
|
2013
|
2012
|
2013
|
2012
|
|||||||||||||||||||||||
|
|
(millions)
|
||||||||||||||||||||||||||||||
|
Realized gains
|
$
|
40
|
|
$
|
75
|
|
$
|
17
|
|
$
|
20
|
|
$
|
103
|
|
$
|
206
|
|
$
|
48
|
|
$
|
81
|
|
|||||||
|
Realized losses
|
$
|
26
|
|
$
|
16
|
|
$
|
18
|
|
$
|
12
|
|
$
|
69
|
|
$
|
48
|
|
$
|
48
|
|
$
|
34
|
|
|||||||
|
Proceeds from sale or maturity of securities
|
$
|
822
|
|
$
|
953
|
|
$
|
613
|
|
$
|
592
|
|
$
|
2,604
|
|
$
|
3,890
|
|
$
|
1,967
|
|
$
|
2,949
|
|
|||||||
The unrealized gains on available for sale securities are as follows:
|
|
NEE
|
FPL
|
|||||||||||||
|
|
September 30, 2013
|
December 31, 2012
|
September 30, 2013
|
December 31, 2012
|
|||||||||||
|
|
(millions)
|
||||||||||||||
|
Equity securities
|
$
|
1,029
|
|
$
|
680
|
|
$
|
759
|
|
$
|
521
|
|
|||
|
Debt securities
|
$
|
47
|
|
$
|
92
|
|
$
|
41
|
|
$
|
77
|
|
|||
The unrealized losses on available for sale debt securities and the fair value of available for sale debt securities in an unrealized loss position are as follows:
|
|
NEE
|
FPL
|
|||||||||||||
|
|
September 30, 2013
|
December 31, 2012
|
September 30, 2013
|
December 31, 2012
|
|||||||||||
|
|
(millions)
|
||||||||||||||
|
Unrealized losses
(a)
|
$
|
27
|
|
$
|
3
|
|
$
|
21
|
|
$
|
2
|
|
|||
|
Fair value
|
$
|
708
|
|
$
|
277
|
|
$
|
543
|
|
$
|
223
|
|
|||
————————————
|
(a)
|
Unrealized losses on available for sale debt securities for securities in an unrealized loss position for greater than twelve months at
September 30, 2013
and
December 31, 2012
were not material to NEE or FPL.
|
Regulations issued by the Federal Energy Regulatory Commission (FERC) and the NRC provide general risk management guidelines to protect nuclear decommissioning funds and to allow such funds to earn a reasonable return. The FERC regulations prohibit, among other investments, investments in any securities of NEE or its subsidiaries, affiliates or associates, excluding investments tied to market indices or mutual funds. Similar restrictions applicable to the decommissioning funds for NEER's nuclear plants are included in the NRC operating licenses for those facilities or in NRC regulations applicable to NRC licensees not in cost-of-service environments. With respect to the decommissioning fund for NEER's Seabrook Station (Seabrook), decommissioning fund contributions and withdrawals are also regulated by the Nuclear Decommissioning Financing Committee pursuant to New Hampshire law.
The nuclear decommissioning reserve funds are managed by investment managers who must comply with the guidelines of NEE and FPL and the rules of the applicable regulatory authorities. The funds' assets are invested giving consideration to taxes, liquidity, risk, diversification and other prudent investment objectives.
Interest Rate and Foreign Currency Contracts
- NEE and its subsidiaries use a combination of fixed rate and variable rate debt to manage interest rate exposure. Interest rate contracts are used to mitigate and adjust interest rate exposure when deemed appropriate based upon market conditions or when required by financing agreements. In addition, with respect to certain debt issuances and borrowings, NEECH has two cross currency swaps to hedge against currency movements with respect to both interest and principal payments and a cross currency swap to hedge against currency and interest rate movements with respect to both interest and principal payments. See Note 2.
25
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
5. Income Taxes
NEE's effective income tax rates for the three months ended September 30, 2013 and 2012 were approximately
30%
and
27%
, respectively. The reduction from the federal statutory rate for those respective periods mainly reflects the benefit of wind production tax credits (PTCs) of approximately $
36 million
and $
35 million
, respectively, related to NEER's wind projects and deferred income tax benefits associated with grants (convertible investment tax credits (ITCs)) under the American Recovery and Reinvestment Act of 2009, as amended (Recovery Act), of approximately $
29 million
and $
14 million
, respectively, primarily for certain wind and solar projects expected to be placed in service.
NEE's effective income tax rates for the nine months ended September 30, 2013 and 2012 were approximately
33%
and
27%
, respectively. The increase in the rate for the nine months ended September 30, 2013 is primarily due to the establishment of a full valuation allowance during the first quarter of 2013 of approximately $
132 million
on the deferred tax assets associated with the Spain solar projects. This valuation allowance primarily related to deferred tax assets created as a result of the $
300 million
impairment and other related charges ($
342 million
after-tax) recorded during the first quarter of 2013 (see Note 3 - Nonrecurring Fair Value Measurements). In addition, the rates for both periods reflect the effect of PTCs of approximately $
161 million
and $
147 million
, respectively, for wind projects at NEER and deferred income tax benefits associated with convertible ITCs of approximately $
62 million
and $
37 million
, respectively, primarily for certain wind and solar projects expected to be placed in service.
NEE recognizes PTCs as wind energy is generated and sold based on a per kilowatt-hour (kWh) rate prescribed in applicable federal and state statutes, which may differ significantly from amounts computed, on a quarterly basis, using an overall effective income tax rate anticipated for the full year. NEE uses this method of recognizing PTCs for specific reasons, including that PTCs are an integral part of the financial viability of most wind projects and a fundamental component of such wind projects' results of operations. PTCs, as well as deferred income tax benefits associated with convertible ITCs, can significantly affect NEE's effective income tax rate depending on the amount of pretax income. The amount of PTCs recognized can be significantly affected by wind generation and by the roll off of PTCs after ten years of production (PTC roll off).
6. Discontinued Operations
In March 2013, a subsidiary of NEER completed the sale of its ownership interest in a portfolio of hydropower generation plants and related assets (hydro sale) with a total generating capacity of
351
MW located in Maine and New Hampshire. The sales price primarily included the assumption by the buyer of
$700
million in related debt.
In connection with the sale, a gain of approximately
$372
million (
$231
million after-tax) is reflected in net gain from discontinued operations, net of income taxes in NEE's condensed consolidated statements of income for the nine months ended September 30, 2013. The assets and liabilities related to the hydro sale were classified as assets held for sale and liabilities associated with assets held for sale on NEE's condensed consolidated balance sheet at December 31, 2012. The operations of the hydropower generation plants, exclusive of the gain, were not material to NEE's condensed consolidated statements of income for the nine months ended September 30, 2013 or 2012 or for the three months ended September 30, 2012.
In March 2013, NEER initiated a plan and received internal authorization to pursue the sale of its ownership interests in oil-fired generating plants located in Maine (Maine fossil) with a total generating capacity of
796
MW. In connection with the decision to sell Maine fossil, a loss of approximately
$67
million (
$43
million after-tax) is reflected in net gain from discontinued operations, net of income taxes in NEE's condensed consolidated statements of income for the nine months ended September 30, 2013. The fair value measurement (Level 3) was based on the estimated sales price less the estimated costs to sell. The estimated sales price was estimated using an income approach based primarily on capacity revenue forecasts. The carrying amount of the assets and liabilities and the operations, exclusive of the loss, of Maine fossil were not material to NEE's condensed consolidated financial statements as of September 30, 2013 or for the three or nine months ended September 30, 2013 or 2012.
26
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
7. Variable Interest Entities (VIEs)
As of
September 30, 2013
, NEE has
twelve
VIEs which it consolidates and has interests in certain other VIEs which it does not consolidate.
FPL
- FPL is considered the primary beneficiary of, and therefore consolidates, a VIE that is a wholly-owned bankruptcy remote special purpose subsidiary that it formed in 2007 for the sole purpose of issuing storm-recovery bonds pursuant to the securitization provisions of the Florida Statutes and a financing order of the FPSC. FPL is considered the primary beneficiary because FPL has the power to direct the significant activities of the VIE, and its equity investment, which is subordinate to the bondholder's interest in the VIE, is at risk. Storm restoration costs incurred by FPL during 2005 and 2004 exceeded the amount in FPL's funded storm and property insurance reserve, resulting in a storm reserve deficiency. In 2007, the VIE issued $
652 million
aggregate principal amount of senior secured bonds (storm-recovery bonds), primarily for the after-tax equivalent of the total of FPL's unrecovered balance of the 2004 storm restoration costs, the 2005 storm restoration costs and to reestablish FPL's storm and property insurance reserve. In connection with this financing, net proceeds, after debt issuance costs, to the VIE (approximately $
644 million
) were used to acquire the storm-recovery property, which includes the right to impose, collect and receive a storm-recovery charge from all customers receiving electric transmission or distribution service from FPL under rate schedules approved by the FPSC or under special contracts, certain other rights and interests that arise under the financing order issued by the FPSC and certain other collateral pledged by the VIE that issued the bonds. The storm-recovery bonds are payable only from and are secured by the storm-recovery property. The bondholders have no recourse to the general credit of FPL. The assets of the VIE were approximately $
315 million
and $
366 million
at
September 30, 2013
and
December 31, 2012
, respectively, and consisted primarily of storm-recovery property, which are included in securitized storm-recovery costs on NEE's and FPL's condensed consolidated balance sheets. The liabilities of the VIE were approximately $
389 million
and $
447 million
at
September 30, 2013
and
December 31, 2012
, respectively, and consisted primarily of storm-recovery bonds, which are included in long-term debt on NEE's and FPL's condensed consolidated balance sheets.
FPL identified a potential VIE, which is considered a qualifying facility as defined by the Public Utility Regulatory Policies Act of 1978, as amended (PURPA). PURPA requires utilities, such as FPL, to purchase the electricity output of a qualifying facility. FPL entered into a purchased power agreement effective in 1994 with this
250
MW coal-fired qualifying facility to purchase substantially all of the facility's capacity and electrical output over a substantial portion of its estimated useful life. FPL absorbs a portion of the facility's variability related to changes in the market price of coal through the price it pays per MWh (energy payment). After making exhaustive efforts, FPL was unable to obtain the information from the facility necessary to determine whether the facility is a VIE or whether FPL is the primary beneficiary of the facility. The purchased power agreement with the facility contains no provision which legally obligates the facility to release this information to FPL. The energy payments paid by FPL will fluctuate as coal prices change. This fluctuation does not expose FPL to losses since the energy payments paid by FPL to the facility are recovered through the fuel clause as approved by the FPSC. Notwithstanding the fact that FPL's energy payments are recovered through the fuel clause, if the facility was determined to be a VIE, the absorption of some of the facility's fuel price variability might cause FPL to be considered the primary beneficiary. During the
three months ended September 30, 2013
and
2012
, FPL purchased
287,029
MWh and
293,650
MWh, respectively, from the facility at a total cost of approximately $
41 million
and $
48 million
, respectively. During the
nine months ended September 30, 2013
and
2012
, FPL purchased
568,897
MWh and
582,661
MWh, respectively, from the facility at a total cost of approximately $
114 million
and $
133 million
, respectively.
Additionally, FPL entered into a purchased power agreement effective in 1995 with a
330
MW coal-fired qualifying facility to purchase substantially all of the facility's electrical output over a substantial portion of its estimated useful life. The facility is considered a VIE because FPL absorbs a portion of the facility’s variability related to changes in the market price of coal through the energy payment. Since FPL does not control the most significant activities of the facility, including operations and maintenance, FPL is not the primary beneficiary and does not consolidate this VIE. The energy payments paid by FPL will fluctuate as coal prices change. This fluctuation does not expose FPL to losses since the energy payments paid by FPL to the facility are recovered through the fuel clause as approved by the FPSC.
NEER
- NEE consolidates
eleven
NEER VIEs. NEER is considered the primary beneficiary of these VIEs since NEER controls the most significant activities of these VIEs, including operations and maintenance, and through its
100
% equity ownership has the obligation to absorb expected losses of these VIEs.
A
NEER VIE consolidates two entities which own and operate natural gas/oil electric generating facilities with the capability of producing
110
MW. This VIE sells its electric output under power sales contracts to a third party, with expiration dates in
2018
and
2020
. The power sales contracts provide the offtaker the ability to dispatch the facilities and require the offtaker to absorb the cost of fuel. This VIE uses third-party debt and equity to finance its operations. The debt is secured by liens against the generating facilities and the other assets of these entities. The debt holders have no recourse to the general credit of NEER for the repayment of debt. The assets and liabilities of the VIE were approximately $
92 million
and $
67 million
, respectively, at
September 30, 2013
and $
90 million
and $
70 million
, respectively, at
December 31, 2012
, and consisted primarily of property, plant and equipment and long-term debt.
27
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
The other
ten
NEER VIEs consolidate several entities which own and operate wind electric generating facilities with the capability of producing a total of
3,219
MW.
Nine
of these VIEs sell their electric output under power sales contracts to third parties with expiration dates ranging from
2018
through
2037
; the
tenth
VIE sells its electric output in the spot market. The VIEs use third-party debt and/or equity to finance their operations. Certain investors that hold no equity interest in the VIEs hold differential membership interests, which give them the right to receive a portion of the economic attributes of the generating facilities, including certain tax attributes. The debt is secured by liens against the generating facilities and the other assets of these entities. The debt holders have no recourse to the general credit of NEER for the repayment of debt. The assets and liabilities of these VIEs totaled approximately $
4.8 billion
and $
3.2 billion
, respectively, at
September 30, 2013
.
Nine
of the ten were VIEs at December 31, 2012 and were consolidated; the assets and liabilities of those VIEs totaled approximately $
4.6 billion
and $
3.2 billion
, respectively, at
December 31, 2012
. At
September 30, 2013
and
December 31, 2012
, the assets and liabilities of the VIEs consisted primarily of property, plant and equipment, deferral related to differential membership interests and long-term debt.
Other
- As of
September 30, 2013
and
December 31, 2012
, several NEE subsidiaries have investments totaling approximately $
711 million
($
547 million
at FPL) and $
753 million
($
583 million
at FPL), respectively, in certain special purpose entities, which consisted primarily of investments in mortgage-backed securities. These investments are included in special use funds and other investments on NEE's condensed consolidated balance sheets and in special use funds on FPL's condensed consolidated balance sheets. As of
September 30, 2013
, NEE subsidiaries are not the primary beneficiary and therefore do not consolidate any of these entities because they do not control any of the ongoing activities of these entities, were not involved in the initial design of these entities and do not have a controlling financial interest in these entities.
8. Common Shareholders' Equity
Earnings Per Share
- The reconciliation of NEE's basic and diluted earnings per share of common stock from continuing operations is as follows:
|
Three Months Ended September 30,
|
Nine Months Ended September 30,
|
||||||||||||||
|
|
2013
|
2012
|
2013
|
2012
|
|||||||||||
|
(millions, except per share amounts)
|
|||||||||||||||
|
Numerator - income from continuing operations
|
$
|
698
|
|
$
|
415
|
|
$
|
1,393
|
|
$
|
1,482
|
|
|||
|
Denominator:
|
|
|
|
|
|
||||||||||
|
Weighted-average number of common shares outstanding - basic
|
423.8
|
|
419.3
|
|
422.2
|
|
415.6
|
|
|||||||
|
Performance share awards, options, equity units and restricted stock
(a)
|
3.0
|
|
2.4
|
|
2.6
|
|
2.4
|
|
|||||||
|
Weighted-average number of common shares outstanding - assuming dilution
|
426.8
|
|
421.7
|
|
424.8
|
|
418.0
|
|
|||||||
|
Earnings per share of common stock from continuing operations:
|
|
|
|
|
|
||||||||||
|
Basic
|
$
|
1.65
|
|
$
|
0.99
|
|
$
|
3.30
|
|
$
|
3.57
|
|
|||
|
Assuming dilution
|
$
|
1.64
|
|
$
|
0.98
|
|
$
|
3.28
|
|
$
|
3.55
|
|
|||
————————————
|
(a)
|
Performance share awards are included in diluted weighted-average number of common shares outstanding based upon what would be issued if the end of the reporting period was the end of the term of the award. Performance share awards, options, equity units and restricted stock are included in diluted weighted-average number of common shares outstanding by applying the treasury stock method.
|
Common shares issuable pursuant to equity units, stock options, performance shares and restricted stock awards which were not included in the denominator above due to their antidilutive effect were approximately
6.0 million
and
3.2 million
for the
three months ended September 30, 2013 and 2012
, respectively, and
0.9 million
and
9.9 million
for the
nine months ended September 30, 2013 and 2012
, respectively.
28
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Accumulated Other Comprehensive Income (Loss)
- The components of AOCI, net of tax, for the three and nine months ended September 30, 2013 are as follows:
|
Accumulated Other Comprehensive Income (Loss)
|
|||||||||||||||||||||||
|
Net Unrealized Gains (Losses) on Cash Flow Hedges
|
Net Unrealized Gains (Losses) on Available for Sale Securities
|
Defined Benefit Pension and Other Benefits Plans
|
Net Unrealized Gains (Losses) on Foreign Currency Translation
|
Other Comprehensive Income (Loss) Related to Equity Method Investee
|
Total
|
||||||||||||||||||
|
(millions)
|
|||||||||||||||||||||||
|
Three months ended September 30, 2013
|
|||||||||||||||||||||||
|
Balances, June 30, 2013
|
$
|
(126
|
)
|
$
|
128
|
|
$
|
(67
|
)
|
$
|
(20
|
)
|
$
|
(17
|
)
|
$
|
(102
|
)
|
|||||
|
Other comprehensive income (loss) before reclassifications
|
(18
|
)
|
30
|
|
—
|
|
6
|
|
—
|
|
18
|
|
|||||||||||
|
Amounts reclassified from AOCI
|
9
|
|
(a)
|
(7
|
)
|
(b)
|
—
|
|
—
|
|
—
|
|
2
|
|
|||||||||
|
Net other comprehensive income (loss)
|
(9
|
)
|
23
|
|
—
|
|
6
|
|
—
|
|
20
|
|
|||||||||||
|
Balances, September 30, 2013
|
$
|
(135
|
)
|
$
|
151
|
|
$
|
(67
|
)
|
$
|
(14
|
)
|
$
|
(17
|
)
|
$
|
(82
|
)
|
|||||
————————————
|
(a)
|
Reclassified to interest expense in NEE's condensed consolidated statements of income.
|
|
(b)
|
Reclassified to gains on disposal of assets - net in NEE's condensed consolidated statements of income.
|
|
Accumulated Other Comprehensive Income (Loss)
|
|||||||||||||||||||||||
|
Net Unrealized Gains (Losses) on Cash Flow Hedges
|
Net Unrealized Gains (Losses) on Available for Sale Securities
|
Defined Benefit Pension and Other Benefits Plans
|
Net Unrealized Gains (Losses) on Foreign Currency Translation
|
Other Comprehensive Income (Loss) Related to Equity Method Investee
|
Total
|
||||||||||||||||||
|
(millions)
|
|||||||||||||||||||||||
|
Nine months ended September 30, 2013
|
|||||||||||||||||||||||
|
Balances, December 31, 2012
|
$
|
(266
|
)
|
$
|
96
|
|
$
|
(74
|
)
|
$
|
12
|
|
$
|
(23
|
)
|
$
|
(255
|
)
|
|||||
|
Other comprehensive income (loss) before reclassifications
|
83
|
|
72
|
|
6
|
|
(26
|
)
|
6
|
|
141
|
|
|||||||||||
|
Amounts reclassified from AOCI
|
48
|
|
(a)
|
(17
|
)
|
(b)
|
1
|
|
—
|
|
—
|
|
32
|
|
|||||||||
|
Net other comprehensive income (loss)
|
131
|
|
55
|
|
7
|
|
(26
|
)
|
6
|
|
173
|
|
|||||||||||
|
Balances, September 30, 2013
|
$
|
(135
|
)
|
$
|
151
|
|
$
|
(67
|
)
|
$
|
(14
|
)
|
$
|
(17
|
)
|
$
|
(82
|
)
|
|||||
————————————
|
(a)
|
Reclassified to interest expense in NEE's condensed consolidated statements of income.
|
|
(b)
|
Reclassified to gains on disposal of assets - net in NEE's condensed consolidated statements of income.
|
29
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Significant long-term debt issuances and borrowings by subsidiaries of NEE during the
nine months ended September 30, 2013
were as follows:
|
Date Issued
|
Company
|
Debt Issuances/Borrowings
|
Interest
Rate
|
|
Principal
Amount
|
Maturity
Date
|
||||||||
|
|
|
|
|
|
(millions)
|
|
||||||||
|
January - September 2013
|
NEECH and NEER subsidiary
|
Canadian revolving credit agreements
|
Variable
|
|
(a)
|
$
|
189
|
|
Various
|
|||||
|
January - September 2013
|
NEER subsidiaries
|
Euro-denominated senior secured limited-recourse loan
|
Variable
|
|
(a)(b)
|
$
|
106
|
|
2030
|
(c)
|
||||
|
August - September 2013
|
NEER subsidiary
|
Term loan facility
|
Variable
|
|
(a)
|
$
|
62
|
|
2019
|
|||||
|
January - March 2013
|
Lone Star Transmission, LLC
|
Senior secured limited-recourse loan
|
Variable
|
|
(a)
|
$
|
77
|
|
2016
|
|||||
|
January 2013
|
NEECH
|
Junior subordinated debentures
|
5.00
|
%
|
$
|
450
|
|
2073
|
||||||
|
May 2013
|
NEER subsidiary
|
Senior secured limited-recourse term loan
|
Variable
|
|
(d)
|
$
|
1,150
|
|
2020
|
|||||
|
June 2013
|
FPL
|
First mortgage bonds
|
2.75
|
%
|
$
|
500
|
|
2023
|
||||||
|
June 2013
|
NEECH
|
Debentures
|
3.625
|
%
|
$
|
250
|
|
2023
|
||||||
|
June 2013
|
NEER subsidiary
|
Senior secured limited-recourse term loan
|
Variable
|
|
(a)(b)
|
$
|
254
|
|
2031
|
|||||
|
July 2013
|
NEER subsidiary
|
Senior secured limited-recourse term loan
|
Variable
|
|
(a)(b)
|
$
|
66
|
|
2021
|
|||||
|
September 2013
|
NEECH
|
Debentures related to NEE's equity units
|
1.45
|
%
|
$
|
500
|
|
2018
|
||||||
|
(a)
|
Variable rate is based on an underlying index plus a margin.
|
|
(b)
|
Interest rate swap agreements have been entered into with respect to these issuances. See Note 2.
|
|
(c)
|
See Note 10 - Spain Solar Projects for discussion of a default on the senior secured limited-recourse loan.
|
|
(d)
|
Variable rate is based on the greater of an underlying index or a floor, plus a margin.
|
In August 2013, NEECH completed a remarketing of approximately $
402.4 million
aggregate principal amount of its Series D Debentures due September 1, 2015, which constitutes a portion of the $
402.5 million
aggregate principal amount of such debentures (Debentures) that were issued in September 2010 as components of equity units issued concurrently by NEE (2010 equity units). The Debentures are guaranteed by NEE. In connection with the remarketing of the Debentures, the interest rate on the Debentures was reset to
1.339%
per year, and interest is payable on March 1 and September 1 of each year, commencing September 1, 2013. In connection with the settlement of the contracts to purchase NEE common stock that were issued as components of the 2010 equity units, in August and September 2013, NEE issued a total of
5,946,530
shares of common stock in exchange for $
402.5 million
.
In September 2013, NEE sold
$500 million
of equity units (initially consisting of Corporate Units). Each equity unit has a stated amount of
$50
and consists of a contract to purchase NEE common stock (stock purchase contract) and, initially, a
5%
undivided beneficial ownership interest in a Series G Debenture due September 1, 2018 issued in the principal amount of
$1,000
by NEECH (see table above). Each stock purchase contract requires the holder to purchase by no later than September 1, 2016 (the final settlement date) for a price of
$50
in cash, a number of shares of NEE common stock (subject to antidilution adjustments) based on a price per share range of
$82.70
to
$99.24
. If purchased on the final settlement date, as of September 30, 2013, the number of shares issued would (subject to antidilution adjustments) range from
0.6046
shares if the applicable mar
ket value of a share of common stock is
less than or equal to
$82.70
to
0.5038
shares if the applicable market value of a share i
s equal to or greater than
$99.24
, with applicable market value to be determined using the average closing prices of NEE common stock o
ver a
20
-day trading period ending August 29, 2016. Total annual distributions on the equity units will be at the rate of
5.799%
, consisting of interest on the debentures (
1.45%
per year) and payments under the stock purchase contracts (
4.349%
per year). The interest rate on the debentures is expected to be reset on or after March 1, 2016. The holder of the equity unit may satisfy its purchase obligation with proceeds raised from remarketing the NEECH debentures that are part of its equity unit. The undivided beneficial ownership interest in the NEECH debenture that is a component of each Corporate Unit is pledged to NEE to secure the holder's obligation to purchase NEE common stock under the related stock purchase contract. If a successful remarketing does not occur on or before the third business day prior to the final settlement date, and a holder has not notified NEE of its intention to settle the stock purchase contract with cash, the debentures that are components of the Corporate Units will be used to satisfy in full the holders' obligations to purchase NEE common stock under the related stock purchase contracts on the final settlement date. The debentures are fully and unconditionally guaranteed by NEE.
30
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
10. Commitments and Contingencies
Commitments
- NEE and its subsidiaries have made commitments in connection with a portion of their projected capital expenditures. Capital expenditures at FPL include, among other things, the cost for construction or acquisition of additional facilities and equipment to meet customer demand, as well as capital improvements to and maintenance of existing facilities and the procurement of nuclear fuel. At NEER, capital expenditures include, among other things, the cost, including capitalized interest, for construction of wind and solar projects and the procurement of nuclear fuel. Capital expenditures for Corporate and Other include, among other things, the cost to meet customer-specific requirements and maintain the fiber-optic network for the fiber-optic telecommunications business (FPL FiberNet) and the cost to maintain existing transmission facilities at NextEra Energy Transmission, LLC (NEET).
At
September 30, 2013
, estimated capital expenditures for the remainder of 2013 through 2017 were as follows:
|
|
Remainder of 2013
|
2014
|
2015
|
2016
|
2017
|
Total
|
|||||||||||||||||
|
|
(millions)
|
||||||||||||||||||||||
|
FPL:
|
|
|
|
|
|
|
|||||||||||||||||
|
Generation:
(a)
|
|
|
|
|
|
|
|||||||||||||||||
|
New
(b)(c)
|
$
|
195
|
|
$
|
710
|
|
$
|
290
|
|
$
|
75
|
|
$
|
—
|
|
$
|
1,270
|
|
|||||
|
Existing
|
245
|
|
760
|
|
730
|
|
600
|
|
540
|
|
2,875
|
|
|||||||||||
|
Transmission and distribution
|
235
|
|
1,205
|
|
1,105
|
|
1,070
|
|
795
|
|
4,410
|
|
|||||||||||
|
Nuclear fuel
|
115
|
|
140
|
|
210
|
|
220
|
|
225
|
|
910
|
|
|||||||||||
|
General and other
|
60
|
|
160
|
|
110
|
|
125
|
|
120
|
|
575
|
|
|||||||||||
|
Total
(d)
|
$
|
850
|
|
$
|
2,975
|
|
$
|
2,445
|
|
$
|
2,090
|
|
$
|
1,680
|
|
$
|
10,040
|
|
|||||
|
NEER:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
|
Wind
(e)
|
$
|
455
|
|
$
|
660
|
|
$
|
115
|
|
$
|
10
|
|
$
|
5
|
|
$
|
1,245
|
|
|||||
|
Solar
(f)
|
130
|
|
455
|
|
825
|
|
530
|
|
—
|
|
1,940
|
|
|||||||||||
|
Nuclear
(g)
|
115
|
|
315
|
|
280
|
|
305
|
|
245
|
|
1,260
|
|
|||||||||||
|
Other
(h)
|
65
|
|
40
|
|
15
|
|
75
|
|
40
|
|
235
|
|
|||||||||||
|
Total
|
$
|
765
|
|
$
|
1,470
|
|
$
|
1,235
|
|
$
|
920
|
|
$
|
290
|
|
$
|
4,680
|
|
|||||
|
Corporate and Other
(i)
|
$
|
25
|
|
$
|
75
|
|
$
|
70
|
|
$
|
60
|
|
$
|
70
|
|
$
|
300
|
|
|||||
|
(a)
|
Includes allowance for funds used during construction (AFUDC) of approximately $
19 million
, $
48 million
, $
57 million
and $
26 million
for the remainder of 2013 through 2016, respectively.
|
|
(b)
|
Includes land, generating structures, transmission interconnection and integration and licensing.
|
|
(c)
|
Consists of projects that have received FPSC approval. Excludes capital expenditures for the construction costs for the two additional nuclear units at FPL's Turkey Point site beyond what is required to receive an NRC license for each unit.
|
|
(d)
|
FPL has identified $
1.5 billion
to $
2.5 billion
in potential incremental capital expenditures through 2016 in addition to what is included in the table above.
|
|
(e)
|
Consists of capital expenditures for new wind projects and related transmission totaling approximately
710
MW, including approximately
385
MW in Canada, that have received applicable internal approvals. Excludes new Canadian wind projects requiring internal approvals with generation totaling approximately
80
MW in 2014, with an estimated remaining cost of approximately
$200
million. NEER expects to add up to
1,500
MW of new U.S. wind generation through 2014 at a total cost of up to
$3
billion.
|
|
(f)
|
Consists of capital expenditures for new solar projects and related transmission totaling
1,045
MW that have received applicable internal approvals, including equity contributions associated with a 50% equity investment in a
550
MW solar project. Includes approximately
$1.1
billion of estimated costs associated with the pending acquisition of a
250
MW solar project that is expected to close in early 2014, subject to certain conditions precedent, and complete construction in 2016.
|
|
(g)
|
Includes nuclear fuel.
|
|
(h)
|
Consists of capital expenditures that have received applicable internal approvals.
|
|
(i)
|
Excludes new natural gas pipeline system requiring certain external and internal approvals with an estimated total cost of approximately
$1.6 billion
. See Part II, Item 5. (c)(i) in the Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2013 for NEE and FPL.
|
In October 2013, NEER obtained internal approvals for approximately
850
MW of new U.S. wind projects and the remaining
80
MW of new Canadian wind projects, all of which are expected to come into service in 2014 and 2015, at estimated costs totaling approximately
$1.6
billion.
The above estimates are subject to continuing review and adjustment and actual capital expenditures may vary significantly from these estimates.
31
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Contracts
- In addition to the commitments made in connection with the estimated capital expenditures included in the table in Commitments above, FPL has commitments under long-term purchased power and fuel contracts. As of
September 30, 2013
, FPL is obligated under take-or-pay purchased power contracts with JEA and with subsidiaries of The Southern Company (Southern subsidiaries) to pay for approximately
1,330
MW annually
through 2015
and
375
MW annually thereafter
through 2021
. FPL also has various firm pay-for-performance contracts to purchase approximately
705
MW from certain cogenerators and small power producers (qualifying facilities) with expiration dates ranging from
2024 through 2034
. The purchased power contracts provide for capacity and energy payments. Energy payments are based on the actual power taken under these contracts. Capacity payments for the pay-for-performance contracts are subject to the qualifying facilities meeting certain contract conditions. FPL has contracts with expiration dates
through 2036
for the purchase and transportation of natural gas and coal, and storage of natural gas.
As of
September 30, 2013
, NEER has entered into contracts with expiration dates ranging from
November 2013
through
2030
primarily for the purchase of solar reflectors, wind turbines and towers, steam turbine generators and heat collection elements and related construction and development activities, as well as for the supply of uranium, conversion, enrichment and fabrication of nuclear fuel. Approximately
$1.9 billion
of commitments under such contracts are included in the estimated capital expenditures table in Commitments above. In addition, NEER has contracts primarily for the purchase, transportation and storage of natural gas and firm transmission service with expiration dates ranging from
November 2013
through
2033
.
The required capacity and/or minimum payments under the contracts discussed above as of
September 30, 2013
were estimated as follows:
|
Remainder of 2013
|
2014
|
2015
|
2016
|
2017
|
Thereafter
|
||||||||||||||||||
|
(millions)
|
|||||||||||||||||||||||
|
FPL:
|
|||||||||||||||||||||||
|
Capacity charges:
(a)
|
|||||||||||||||||||||||
|
Qualifying facilities
|
$
|
70
|
|
$
|
285
|
|
$
|
290
|
|
$
|
250
|
|
$
|
255
|
|
$
|
2,225
|
|
|||||
|
JEA and Southern subsidiaries
|
$
|
55
|
|
$
|
215
|
|
$
|
195
|
|
$
|
70
|
|
$
|
50
|
|
$
|
10
|
|
|||||
|
Minimum charges, at projected prices:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
|
Natural gas, including transportation and storage
(b)
|
$
|
475
|
|
$
|
1,535
|
|
$
|
570
|
|
$
|
535
|
|
$
|
530
|
|
$
|
6,400
|
|
|||||
|
Coal
(b)
|
$
|
25
|
|
$
|
55
|
|
$
|
20
|
|
$
|
20
|
|
$
|
—
|
|
$
|
—
|
|
|||||
|
NEER
|
$
|
840
|
|
$
|
1,025
|
|
$
|
130
|
|
$
|
160
|
|
$
|
85
|
|
$
|
590
|
|
|||||
|
Corporate and Other
(c)(d)
|
$
|
40
|
|
$
|
20
|
|
$
|
15
|
|
$
|
10
|
|
$
|
10
|
|
$
|
10
|
|
|||||
|
(a)
|
Capacity charges under these contracts, substantially all of which are recoverable through the capacity clause, totaled approximately $
121 million
and $
129 million
for the
three months ended September 30, 2013 and 2012
, respectively, and approximately $
365 million
and $
391 million
for the
nine months ended September 30, 2013 and 2012
, respectively. Energy charges under these contracts, which are recoverable through the fuel clause, totaled approximately $
93 million
and $
110 million
for the
three months ended September 30, 2013 and 2012
, respectively, and approximately $
202 million
and $
232 million
for the
nine months ended September 30, 2013 and 2012
, respectively.
|
|
(b)
|
Recoverable through the fuel clause.
|
|
(c)
|
Includes an approximately
$60 million
commitment to invest in clean power and technology businesses through 2021.
|
|
(d)
|
Excludes approximately
$360 million
, in 2013, of joint obligations of NEECH and NEER which are included in the NEER amounts above.
|
On October 28, 2013, the FPSC issued an order approving, subject to a 21-day protest period, FPL's
25-year
natural gas transportation agreements with each of Sabal Trail Transmission, LLC (Sabal Trail, an entity in which a NEECH subsidiary has a
33%
ownership interest), and Florida Southeast Connection, LLC (Florida Southeast Connection, a NEE subsidiary) for a quantity of
400,000
MMBtu/day beginning on May 1, 2017 and increasing to
600,000
MMBtu/day on May 1, 2020. These agreements collectively contain firm commitments by FPL totaling on average approximately
$410 million
annually over the term of the agreements. These firm commitments are contingent upon the occurrence of certain events, including FERC approval and completion of construction of the pipeline to be built by each of Sabal Trail and Florida Southeast Connection.
Insurance
- Liability for accidents at nuclear power plants is governed by the Price-Anderson Act, which limits the liability of nuclear reactor owners to the amount of insurance available from both private sources and an industry retrospective payment plan. In accordance with this Act, NEE maintains $
375 million
of private liability insurance per site, which is the maximum obtainable, and participates in a secondary financial protection system, which provides up to $
13.2 billion
of liability insurance coverage per incident at any nuclear reactor in the United States. Under the secondary financial protection system, NEE is subject to retrospective assessments of up to $
1.0 billion
($
509 million
for FPL), plus any applicable taxes, per incident at any nuclear reactor in the United States, payable at a rate not to exceed $
152 million
($
76 million
for FPL) per incident per year. NEE and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook, Duane Arnold Energy Center (Duane Arnold) and St. Lucie Unit No. 2, which approximates $
15 million
, $
38 million
and $
19 million
, plus any applicable taxes, per incident, respectively.
32
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
NEE participates in a nuclear insurance mutual company that provides $
2.75 billion
of limited insurance coverage per occurrence per site for property damage, decontamination and premature decommissioning risks at its nuclear plants. The proceeds from such insurance, however, must first be used for reactor stabilization and site decontamination before they can be used for plant repair. Effective April 1, 2013, a $
1.5 billion
sublimit was established for non-nuclear perils. NEE also participates in an insurance program that provides limited coverage for replacement power costs if a nuclear plant is out of service for an extended period of time because of an accident. In the event of an accident at one of NEE's or another participating insured's nuclear plants, NEE could be assessed up to $
198 million
($
118 million
for FPL), plus any applicable taxes, in retrospective premiums in a policy year. NEE and FPL are contractually entitled to recover a proportionate share of such assessments from the owners of minority interests in Seabrook, Duane Arnold and St. Lucie Unit No. 2, which approximates $
3 million
, $
5 million
and $
4 million
, plus any applicable taxes, respectively.
Due to the high cost and limited coverage available from third-party insurers, NEE does not have property insurance coverage for a substantial portion of its transmission and distribution property and has no property insurance coverage for FPL FiberNet's fiber-optic cable. Should FPL's future storm restoration costs exceed the reserve amount established through the issuance of storm-recovery bonds by a VIE in 2007, FPL may recover storm restoration costs, subject to prudence review by the FPSC, either through surcharges approved by the FPSC or through securitization provisions pursuant to Florida law.
In the event of a loss, the amount of insurance available might not be adequate to cover property damage and other expenses incurred. Uninsured losses and other expenses, to the extent not recovered from customers in the case of FPL or Lone Star Transmission, LLC (Lone Star), would be borne by NEE and/or FPL and/or Lone Star, as the case may be, and could have a material adverse effect on NEE's and FPL's financial condition, results of operations and liquidity.
Spain Solar Projects
- On March 28, 2013 and May 3, 2013, events of default occurred under the project-level financing agreements for the Spain solar projects (project-level financing) as a result of changes of law that occurred in December 2012 and February 2013. These changes of law negatively affected the projected economics of the projects and have caused the project-level financing to be unsupportable by expected future project cash flows. Under the project-level financing, events of default provide for, among other things, a right by the lenders (which they have not exercised to date for the project-level financing) to accelerate the payment of the project-level debt. Accordingly, approximately
$784 million
of debt and
$91 million
of derivative liabilities related to interest rate swaps continue to be classified as current maturities of long-term debt and current derivative liabilities, respectively, on NEE's condensed consolidated balance sheets as of
September 30, 2013
. The parties to the project-level financing agreements have been in negotiations with the lenders to seek to restructure the project-level financing.
In addition, pursuant to Spanish law, the impairment recorded due to the changes of law has caused NextEra Energy España, S.L. en Liquidación (NEE España), the NEER subsidiary in Spain that is the direct shareholder of the project-level subsidiaries (and whose primary assets are the stock of the project-level subsidiaries), to commence liquidation proceedings on October 21, 2013. The commencement of the liquidation process resulted in an additional event of default under the project-level financing agreements and, if not cured or waived within 30 days, also would result in the immediate acceleration of the payment of the debt outstanding (approximately
$202 million
outstanding at September 30, 2013) under a variable rate revolving loan agreement with a lender entered into by NEE España and NEECH, scheduled to mature in April 2014, which NEE España had used to fund a substantial portion of its base equity commitment under the project-level financing agreements (which base equity commitment was guaranteed by NEECH under the project-level financing agreements). NEECH believes that its liability under the project-level financing agreements together with its liability under the variable rate revolving loan agreement should not exceed NEE España’s total base equity commitment under the project-level financing agreements.
In connection with the foregoing, on March 20, 2013, NEECH filed a lawsuit in the U.S. District Court for the Southern District of New York against the lenders requesting that the court confirm NEECH's conclusion that its obligations to the lenders under the project-level financing agreements are limited, as a result of changes of law, to guaranteeing the payment of the remaining unfunded portion of the base equity commitment (approximately
$12 million
remaining at September 30, 2013) as opposed to guaranteeing the payment of all debt outstanding under the project-level financing agreements (
$784 million
at September 30, 2013) as well as associated interest rate swap breakage (
$161 million
at September 30, 2013) and other specified costs. In May 2013, the lenders filed a response to the lawsuit in which they disagree with NEECH's conclusion and contend that NEECH's obligations to guarantee the foregoing amounts have not been limited. There can be no assurance that the court will agree with NEECH's position that its guarantee is limited as a result of changes of law or that the financing arrangements will be successfully restructured.
In July 2013, the Spanish government published a new law that created a new economic framework for the Spanish renewable energy sector. Additional regulatory pronouncements from the Spanish government, which are expected in the first quarter of 2014, are needed to complete and implement the framework. At this time, NEE is unable to assess the framework's ultimate impact on the Spain solar projects which could include further impairment of the Spain solar projects and/or a partial refund of tariff revenues collected since July 2013.
33
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Legal Proceedings
- In November 1999, the Attorney General of the United States, on behalf of the U.S. Environmental Protection Agency (EPA), brought an action in the U.S. District Court for the Northern District of Georgia against Georgia Power Company and other subsidiaries of The Southern Company for certain alleged violations of the Prevention of Significant Deterioration (PSD) provisions and the New Source Performance Standards (NSPS) of the Clean Air Act. In May 2001, the EPA amended its complaint to allege, among other things, that Georgia Power Company constructed and is continuing to operate Scherer Unit No. 4, in which FPL owns an interest of approximately
76%
, without obtaining a PSD permit, without complying with NSPS requirements, and without applying best available control technology for nitrogen oxides, sulfur dioxides and particulate matter as required by the Clean Air Act. It also alleges that unspecified major modifications have been made at Scherer Unit No. 4 that require its compliance with the aforementioned Clean Air Act provisions. The EPA seeks injunctive relief requiring the installation of best available control technology and civil penalties. Under the EPA's civil penalty rules, the EPA could assess up to
$25,000
per day for each violation from an unspecified date after June 1, 1975 through January 30, 1997, up to
$27,500
per day for each violation from January 31, 1997 through March 15, 2004, up to
$32,500
per day for each violation from March 16, 2004 through January 12, 2009 and up to
$37,500
per day for each violation thereafter. Georgia Power Company has answered the amended complaint, asserting that it has complied with all requirements of the Clean Air Act, denying the plaintiff's allegations of liability, denying that the plaintiff is entitled to any of the relief that it seeks and raising various other defenses. In June 2001, a federal district court stayed discovery and administratively closed the case and the EPA has not yet moved to reopen the case. In April 2007, the U.S. Supreme Court in a separate unrelated case rejected an argument that a "major modification" occurs at a plant only when there is a resulting increase in the hourly rate of air emissions. Georgia Power Company has made a similar argument in defense of its case, but has other factual and legal defenses that are unaffected by the U.S. Supreme Court's decision.
In 1995 and 1996, NEE, through an indirect subsidiary, purchased from Adelphia Communications Corporation (Adelphia)
1,091,524
shares of Adelphia common stock and
20,000
shares of Adelphia preferred stock (convertible into
2,358,490
shares of Adelphia common stock) for an aggregate price of approximately
$35,900,000
. On January 29, 1999, Adelphia repurchased all of these shares for
$149,213,130
in cash. In June 2004, Adelphia, Adelphia Cablevision, L.L.C. and the Official Committee of Unsecured Creditors of Adelphia filed a complaint against NEE and its indirect subsidiary in the U.S. Bankruptcy Court, Southern District of New York. The complaint alleges that the repurchase of these shares by Adelphia was a fraudulent transfer, in that at the time of the transaction Adelphia (i) was insolvent or was rendered insolvent, (ii) did not receive reasonably equivalent value in exchange for the cash it paid, and (iii) was engaged or about to engage in a business or transaction for which any property remaining with Adelphia had unreasonably small capital. The complaint seeks the recovery for the benefit of Adelphia's bankruptcy estate of the cash paid for the repurchased shares, plus interest from January 29, 1999. NEE has filed an answer to the complaint. NEE believes that the complaint is without merit because, among other reasons, Adelphia will be unable to demonstrate that (i) Adelphia's repurchase of shares from NEE, which repurchase was at the market value for those shares, was not for reasonably equivalent value, (ii) Adelphia was insolvent at the time of the repurchase, or (iii) the repurchase left Adelphia with unreasonably small capital. The trial was completed in May 2012 and closing arguments were heard in July 2012.
In October 2004, TXU Portfolio Management Company (TXU) served FPL Energy Pecos Wind I, LP, FPL Energy Pecos Wind I GP, LLC, FPL Energy Pecos Wind II, LP, FPL Energy Pecos Wind II GP, LLC and Indian Mesa Wind Farm, LP (NEER Affiliates) as defendants in a civil action filed in the District Court in Dallas County, Texas. FPL Energy, LLC, now known as NextEra Energy Resources, LLC, was added as a defendant in 2005. The petition alleged that the NEER Affiliates had contractual obligations to produce and sell to TXU a minimum quantity of energy and renewable energy credits each year during the period from 2002 through 2005 and that the NEER Affiliates failed to meet this obligation. The plaintiff asserted claims for breach of contract and declaratory judgment and sought damages of approximately
$34 million
plus attorneys' fees, costs and interest. Following a jury trial in 2007, among other findings, both TXU and the NEER Affiliates were found to have breached the contracts. In August 2008, the trial court issued a final judgment holding that the contracts were not terminated and neither party was entitled to recover any damages. In November 2008, TXU appealed the final judgment to the Fifth District Court of Appeals in Dallas, Texas. In an opinion issued in July 2010, the appellate court reversed portions of the trial court's judgment, ruling that the contracts' liquidated damage provision is an enforceable liquidated damages clause. The appellate court ordered that the case be remanded back to the trial court for further proceedings to determine the amount of damages payable by the NEER Affiliates. The NEER Affiliates filed a motion for rehearing of the appellate court’s decision, which motion was denied, and in April 2011 filed a petition for review of the appellate court decision with the Texas Supreme Court. In February 2012, the Texas Supreme Court granted the petition for review and oral arguments were heard in October 2012.
NEE and FPL are vigorously defending, and believe that they or their affiliates have meritorious defenses to, the lawsuits described above. In addition to the legal proceedings discussed above, NEE and its subsidiaries, including FPL, are involved in other legal and regulatory proceedings, actions and claims in the ordinary course of their businesses. Generating plants in which subsidiaries of NEE, including FPL, have an ownership interest are also involved in legal and regulatory proceedings, actions and claims, the liabilities from which, if any, would be shared by such subsidiary. In the event that NEE and FPL, or their affiliates, do not prevail in the lawsuits described above or these other legal and regulatory proceedings, actions and claims, there may be a material adverse effect on their financial statements. While management is unable to predict with certainty the outcome of the lawsuits described above or these other legal and regulatory proceedings, actions and claims, based on current knowledge it is not expected that their ultimate resolution, individually or collectively, will have a material adverse effect on the financial statements of NEE or FPL.
34
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
11. Segment Information
NEE's reportable segments are FPL, a rate-regulated electric utility, and NEER, a competitive energy business. NEER's segment information includes an allocation of interest expense from NEECH based on a deemed capital structure of
70%
debt and allocated shared service costs. Corporate and Other represents other business activities, other segments that are not separately reportable and eliminating entries. NEE's segment information is as follows:
|
Three Months Ended September 30,
|
|||||||||||||||||||||||||||||||
|
2013
|
2012
|
||||||||||||||||||||||||||||||
|
FPL
|
NEER
(a)
|
|
Corporate
and Other
|
NEE
Consoli-
dated
|
FPL
|
NEER
(a)
|
Corporate
and Other
|
NEE
Consoli-
dated
|
|||||||||||||||||||||||
|
|
|
|
|
(millions)
|
|
|
|
||||||||||||||||||||||||
|
Operating revenues
|
$
|
3,020
|
|
$
|
1,281
|
|
|
$
|
93
|
|
$
|
4,394
|
|
$
|
2,975
|
|
$
|
808
|
|
$
|
60
|
|
$
|
3,843
|
|
||||||
|
Operating expenses
|
$
|
2,242
|
|
$
|
904
|
|
$
|
63
|
|
$
|
3,209
|
|
$
|
2,256
|
|
$
|
793
|
|
(b)
|
$
|
52
|
|
$
|
3,101
|
|
||||||
|
Net income (loss)
|
$
|
422
|
|
$
|
281
|
|
(c)
|
$
|
(5
|
)
|
$
|
698
|
|
$
|
392
|
|
$
|
44
|
|
(c)
|
$
|
(21
|
)
|
|
$
|
415
|
|
||||
|
Nine Months Ended September 30,
|
|||||||||||||||||||||||||||||||
|
|
2013
|
2012
|
|||||||||||||||||||||||||||||
|
|
FPL
|
NEER
(a)
|
|
Corporate
and Other
|
|
NEE
Consoli-
dated
|
FPL
|
NEER
(a)
|
Corporate
and Other
|
NEE
Consoli-
dated
|
|||||||||||||||||||||
|
|
|
|
|
|
(millions)
|
|
|
|
|||||||||||||||||||||||
|
Operating revenues
|
$
|
7,905
|
|
$
|
3,343
|
|
|
$
|
258
|
|
|
$
|
11,506
|
|
$
|
7,778
|
|
$
|
2,929
|
|
$
|
174
|
|
$
|
10,881
|
|
|||||
|
Operating expenses
|
$
|
5,860
|
|
$
|
2,860
|
|
(d)
|
$
|
185
|
|
|
$
|
8,905
|
|
$
|
5,916
|
|
$
|
2,271
|
|
(b)
|
$
|
149
|
|
$
|
8,336
|
|
||||
|
Income from continuing operations
|
$
|
1,101
|
|
$
|
295
|
|
(c)
|
$
|
(3
|
)
|
$
|
1,393
|
|
$
|
984
|
|
$
|
516
|
|
(c)
|
$
|
(18
|
)
|
$
|
1,482
|
|
|||||
|
Net gain from discontinued operations, net of income taxes
(e)
|
$
|
—
|
|
$
|
175
|
|
$
|
13
|
|
$
|
188
|
|
$
|
—
|
|
$
|
—
|
|
$
|
—
|
|
$
|
—
|
|
|||||||
|
Net income (loss)
|
$
|
1,101
|
|
$
|
470
|
|
(c)
|
$
|
10
|
|
$
|
1,581
|
|
$
|
984
|
|
$
|
516
|
|
(c)
|
$
|
(18
|
)
|
$
|
1,482
|
|
|||||
|
|
September 30, 2013
|
December 31, 2012
|
|||||||||||||||||||||||||||||
|
|
FPL
|
NEER
|
Corporate
and Other
|
NEE
Consoli-
dated
|
FPL
|
NEER
|
Corporate
and Other
|
NEE
Consoli-
dated
|
|||||||||||||||||||||||
|
|
|
|
|
(millions)
|
|
|
|
||||||||||||||||||||||||
|
Total assets
|
$
|
36,168
|
|
$
|
28,525
|
|
$
|
2,473
|
|
$
|
67,166
|
|
$
|
34,853
|
|
$
|
27,139
|
|
(f)
|
$
|
2,447
|
|
$
|
64,439
|
|
||||||
————————————
|
(a)
|
Interest expense allocated from NEECH is based on a deemed capital structure of
70%
debt. For this purpose, the deferred credit associated with differential membership interests sold by NEER subsidiaries is included with debt. Residual non-utility interest expense is included in Corporate and Other.
|
|
(b)
|
Amount is restated to conform to current year's presentation.
|
|
(c)
|
Includes NEER's tax benefits related to PTCs and for the nine months ended September 30, 2013 also includes after-tax charges of
$342 million
associated with the impairment of the Spain solar projects. See Note 3 - Nonrecurring Fair Value Measurements and Note 5.
|
|
(d)
|
Includes an impairment charge on NEER's Spain solar projects of
$300 million
. See Note 3 - Nonrecurring Fair Value Measurements.
|
|
(e)
|
See Note 6.
|
|
(f)
|
Includes assets held for sale of approximately
$335 million
.
|
35
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
12. Summarized Financial Information of NEECH
NEECH, a
100%
owned subsidiary of NEE, provides funding for, and holds ownership interests in, NEE's operating subsidiaries other than FPL. Most of NEECH's debt, including its debentures, and payment guarantees are fully and unconditionally guaranteed by NEE. Condensed consolidating financial information is as follows:
Condensed Consolidating Statements of Income
|
|
Three Months Ended September 30,
|
||||||||||||||||||||||||||||||
|
|
2013
|
2012
|
|||||||||||||||||||||||||||||
|
|
NEE
(Guarantor)
|
NEECH
|
Other
(a)
|
NEE
Consoli-
dated
|
NEE
(Guarantor)
|
NEECH
|
Other
(a)
|
NEE
Consoli-
dated
|
|||||||||||||||||||||||
|
|
|
|
|
(millions)
|
|
|
|
||||||||||||||||||||||||
|
Operating revenues
|
$
|
—
|
|
$
|
1,377
|
|
$
|
3,017
|
|
$
|
4,394
|
|
$
|
—
|
|
$
|
871
|
|
$
|
2,972
|
|
$
|
3,843
|
|
|||||||
|
Operating expenses
(b)
|
(4
|
)
|
(965
|
)
|
(2,240
|
)
|
(3,209
|
)
|
(5
|
)
|
(843
|
)
|
(2,253
|
)
|
(3,101
|
)
|
|||||||||||||||
|
Interest expense
|
(2
|
)
|
(182
|
)
|
(104
|
)
|
(288
|
)
|
(2
|
)
|
(155
|
)
|
(102
|
)
|
(259
|
)
|
|||||||||||||||
|
Equity in earnings of subsidiaries
|
700
|
|
—
|
|
(700
|
)
|
—
|
|
416
|
|
—
|
|
(416
|
)
|
—
|
|
|||||||||||||||
|
Other income - net
(b)
|
—
|
|
87
|
|
11
|
|
98
|
|
4
|
|
68
|
|
14
|
|
86
|
|
|||||||||||||||
|
Income (loss) before income taxes
|
694
|
|
317
|
|
(16
|
)
|
995
|
|
413
|
|
(59
|
)
|
215
|
|
569
|
|
|||||||||||||||
|
Income tax expense (benefit)
|
(4
|
)
|
38
|
|
263
|
|
297
|
|
(2
|
)
|
(82
|
)
|
238
|
|
154
|
|
|||||||||||||||
|
Net income (loss)
|
$
|
698
|
|
$
|
279
|
|
$
|
(279
|
)
|
$
|
698
|
|
$
|
415
|
|
$
|
23
|
|
$
|
(23
|
)
|
$
|
415
|
|
|||||||
|
|
Nine Months Ended September 30,
|
||||||||||||||||||||||||||||||
|
|
2013
|
2012
|
|||||||||||||||||||||||||||||
|
|
NEE
(Guarantor)
|
NEECH
|
Other
(a)
|
NEE
Consoli-
dated
|
NEE
(Guarantor)
|
NEECH
|
Other
(a)
|
NEE
Consoli-
dated
|
|||||||||||||||||||||||
|
|
|
|
|
(millions)
|
|
|
|
||||||||||||||||||||||||
|
Operating revenues
|
$
|
—
|
|
$
|
3,611
|
|
$
|
7,895
|
|
$
|
11,506
|
|
$
|
—
|
|
$
|
3,112
|
|
$
|
7,769
|
|
$
|
10,881
|
|
|||||||
|
Operating expenses
(b)
|
(11
|
)
|
(3,043
|
)
|
(5,851
|
)
|
(8,905
|
)
|
(13
|
)
|
(2,416
|
)
|
(5,907
|
)
|
(8,336
|
)
|
|||||||||||||||
|
Interest expense
|
(7
|
)
|
(513
|
)
|
(305
|
)
|
(825
|
)
|
(8
|
)
|
(479
|
)
|
(308
|
)
|
(795
|
)
|
|||||||||||||||
|
Equity in earnings of subsidiaries
|
1,572
|
|
—
|
|
(1,572
|
)
|
—
|
|
1,480
|
|
—
|
|
(1,480
|
)
|
—
|
|
|||||||||||||||
|
Other income - net
(b)
|
1
|
|
254
|
|
39
|
|
294
|
|
5
|
|
250
|
|
30
|
|
285
|
|
|||||||||||||||
|
Income from continuing operations before income taxes
|
1,555
|
|
309
|
|
206
|
|
2,070
|
|
1,464
|
|
467
|
|
104
|
|
2,035
|
|
|||||||||||||||
|
Income tax expense (benefit)
|
(13
|
)
|
13
|
|
677
|
|
677
|
|
(18
|
)
|
(29
|
)
|
600
|
|
553
|
|
|||||||||||||||
|
Income (loss) from continuing operations
|
1,568
|
|
296
|
|
(471
|
)
|
1,393
|
|
1,482
|
|
496
|
|
(496
|
)
|
1,482
|
|
|||||||||||||||
|
Net gain from discontinued operations, net of income taxes
|
13
|
|
175
|
|
—
|
|
188
|
|
—
|
|
—
|
|
—
|
|
—
|
|
|||||||||||||||
|
Net income (loss)
|
$
|
1,581
|
|
$
|
471
|
|
$
|
(471
|
)
|
$
|
1,581
|
|
$
|
1,482
|
|
$
|
496
|
|
$
|
(496
|
)
|
$
|
1,482
|
|
|||||||
————————————
(a) Represents FPL and consolidating adjustments.
(b) Prior year amounts are restated to conform to the current year's presentation.
36
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(unaudited)
Condensed Consolidating Statements of Comprehensive Income
|
|
Three Months Ended September 30,
|
||||||||||||||||||||||||||||||
|
|
2013
|
2012
|
|||||||||||||||||||||||||||||
|
|
NEE
(Guarantor)
|
NEECH
|
Other
(a)
|
NEE
Consoli-
dated
|
NEE
(Guarantor)
|
NEECH
|
Other
(a)
|
NEE
Consoli-
dated
|
|||||||||||||||||||||||
|
|
|
|
|
(millions)
|
|
|
|
||||||||||||||||||||||||
|
Comprehensive income (loss)
|
$
|
718
|
|
$
|
298
|
|
$
|
(298
|
)
|
$
|
718
|
|
$
|
386
|
|
$
|
(6
|
)
|
$
|
6
|
|
$
|
386
|
|
|||||||
|
|
Nine Months Ended September 30,
|
||||||||||||||||||||||||||||||
|
|
2013
|
2012
|
|||||||||||||||||||||||||||||
|
|
NEE
(Guarantor)
|
NEECH
|
Other
(a)
|
NEE
Consoli-
dated
|
NEE
(Guarantor)
|
NEECH
|
Other
(a)
|
NEE
Consoli-
dated
|
|||||||||||||||||||||||
|
|
|
|
(millions)
|
||||||||||||||||||||||||||||
|
Comprehensive income (loss)
|
$
|
1,754
|
|
$
|
636
|
|
$
|
(636
|
)
|
$
|
1,754
|
|
$
|
1,417
|
|
$
|
437
|
|
$
|
(437
|
)
|
$
|
1,417
|
|
|||||||
————————————
|
(a)
|
Represents FPL and consolidating adjustments.
|
Condensed Consolidating Balance Sheets
|
|
September 30, 2013
|
December 31, 2012
|
|||||||||||||||||||||||||||||
|
|
NEE
(Guaran-
tor)
|
NEECH
|
Other
(a)
|
NEE
Consoli-
dated
|
NEE
(Guaran-
tor)
|
NEECH
|
Other
(a)
|
NEE
Consoli-
dated
|
|||||||||||||||||||||||
|
|
|
|
|
(millions)
|
|
|
|
||||||||||||||||||||||||
|
PROPERTY, PLANT AND EQUIPMENT
|
|
|
|
|
|
|
|
|
|||||||||||||||||||||||
|
Electric plant in service and other property
|
$
|
32
|
|
$
|
28,439
|
|
$
|
39,384
|
|
$
|
67,855
|
|
$
|
31
|
|
$
|
26,638
|
|
$
|
38,248
|
|
$
|
64,917
|
|
|||||||
|
Less accumulated depreciation and amortization
|
(10
|
)
|
(5,562
|
)
|
(10,884
|
)
|
(16,456
|
)
|
(7
|
)
|
(4,800
|
)
|
(10,697
|
)
|
(15,504
|
)
|
|||||||||||||||
|
Total property, plant and equipment - net
|
22
|
|
22,877
|
|
28,500
|
|
51,399
|
|
24
|
|
21,838
|
|
27,551
|
|
49,413
|
|
|||||||||||||||
|
CURRENT ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
|
Cash and cash equivalents
|
1
|
|
504
|
|
53
|
|
558
|
|
2
|
|
287
|
|
40
|
|
329
|
|
|||||||||||||||
|
Receivables
|
198
|
|
1,212
|
|
831
|
|
2,241
|
|
398
|
|
1,208
|
|
450
|
|
2,056
|
|
|||||||||||||||
|
Other
|
9
|
|
1,515
|
|
1,149
|
|
2,673
|
|
432
|
|
1,421
|
|
999
|
|
2,852
|
|
|||||||||||||||
|
Total current assets
|
208
|
|
3,231
|
|
2,033
|
|
5,472
|
|
832
|
|
2,916
|
|
1,489
|
|
5,237
|
|
|||||||||||||||
|
OTHER ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
|
Investment in subsidiaries
|
17,398
|
|
—
|
|
(17,398
|
)
|
—
|
|
16,064
|
|
—
|
|
(16,064
|
)
|
—
|
|
|||||||||||||||
|
Other
|
720
|
|
4,942
|
|
4,633
|
|
10,295
|
|
647
|
|
4,749
|
|
4,393
|
|
9,789
|
|
|||||||||||||||
|
Total other assets
|
18,118
|
|
4,942
|
|
(12,765
|
)
|
10,295
|
|
16,711
|
|
4,749
|
|
(11,671
|
)
|
9,789
|
|
|||||||||||||||
|
TOTAL ASSETS
|
$
|
18,348
|
|
$
|
31,050
|
|
$
|
17,768
|
|
$
|
67,166
|
|
$
|
17,567
|
|
$
|
29,503
|
|
$
|
17,369
|
|
$
|
64,439
|
|
|||||||
|
CAPITALIZATION
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
|
Common shareholders' equity
|
$
|
17,409
|
|
$
|
4,838
|
|
$
|
(4,838
|
)
|
$
|
17,409
|
|
$
|
16,068
|
|
$
|
3,533
|
|
$
|
(3,533
|
)
|
$
|
16,068
|
|
|||||||
|
Long-term debt
|
—
|
|
15,388
|
|
8,474
|
|
23,862
|
|
—
|
|
14,848
|
|
8,329
|
|
23,177
|
|
|||||||||||||||
|
Total capitalization
|
17,409
|
|
20,226
|
|
3,636
|
|
41,271
|
|
16,068
|
|
18,381
|
|
4,796
|
|
39,245
|
|
|||||||||||||||
|
CURRENT LIABILITIES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
|
Debt due within one year
|
—
|
|
3,913
|
|
935
|
|
4,848
|
|
—
|
|
3,624
|
|
558
|
|
4,182
|
|
|||||||||||||||
|
Accounts payable
|
—
|
|
613
|
|
631
|
|
1,244
|
|
1
|
|
667
|
|
613
|
|
1,281
|
|
|||||||||||||||
|
Other
|
195
|
|
1,711
|
|
1,215
|
|
3,121
|
|
440
|
|
2,317
|
|
659
|
|
3,416
|
|
|||||||||||||||
|
Total current liabilities
|
195
|
|
6,237
|
|
2,781
|
|
9,213
|
|
441
|
|
6,608
|
|
1,830
|
|
8,879
|
|
|||||||||||||||
|
OTHER LIABILITIES AND DEFERRED CREDITS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
|
Asset retirement obligations
|
—
|
|
554
|
|
1,254
|
|
1,808
|
|
—
|
|
508
|
|
1,207
|
|
1,715
|
|
|||||||||||||||
|
Deferred income taxes
|
186
|
|
1,193
|
|
5,828
|
|
7,207
|
|
497
|
|
891
|
|
5,315
|
|
6,703
|
|
|||||||||||||||
|
Other
|
558
|
|
2,840
|
|
4,269
|
|
7,667
|
|
561
|
|
3,115
|
|
4,221
|
|
7,897
|
|
|||||||||||||||
|
Total other liabilities and deferred credits
|
744
|
|
4,587
|
|
11,351
|
|
16,682
|
|
1,058
|
|
4,514
|
|
10,743
|
|
16,315
|
|
|||||||||||||||
|
COMMITMENTS AND CONTINGENCIES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
|
TOTAL CAPITALIZATION AND LIABILITIES
|
$
|
18,348
|
|
$
|
31,050
|
|
$
|
17,768
|
|
$
|
67,166
|
|
$
|
17,567
|
|
$
|
29,503
|
|
$
|
17,369
|
|
$
|
64,439
|
|
|||||||
|
(a)
|
Represents FPL and consolidating adjustments.
|
37
NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Concluded)
(unaudited)
Condensed Consolidating Statements of Cash Flows
|
Nine Months Ended September 30,
|
|||||||||||||||||||||||||||||||
|
2013
|
2012
|
||||||||||||||||||||||||||||||
|
NEE
(Guaran-
tor)
|
NEECH
|
Other
(a)
|
NEE
Consoli-
dated
|
NEE
(Guaran-
tor)
|
NEECH
|
Other
(a)
|
NEE
Consoli-
dated
|
||||||||||||||||||||||||
|
|
|
|
(millions)
|
|
|
|
|||||||||||||||||||||||||
|
NET CASH PROVIDED BY OPERATING ACTIVITIES
|
$
|
1,174
|
|
$
|
494
|
|
$
|
1,722
|
|
$
|
3,390
|
|
$
|
662
|
|
$
|
878
|
|
$
|
1,617
|
|
$
|
3,157
|
|
|||||||
|
CASH FLOWS FROM INVESTING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
|
Capital expenditures, independent power and other investments and nuclear fuel purchases
|
—
|
|
(2,450
|
)
|
(2,209
|
)
|
(4,659
|
)
|
—
|
|
(3,492
|
)
|
(3,197
|
)
|
(6,689
|
)
|
|||||||||||||||
|
Capital contribution to FPL
|
—
|
|
—
|
|
—
|
|
—
|
|
(240
|
)
|
—
|
|
240
|
|
—
|
|
|||||||||||||||
|
Cash grants under the Recovery Act
|
—
|
|
170
|
|
—
|
|
170
|
|
—
|
|
105
|
|
—
|
|
105
|
|
|||||||||||||||
|
Change in loan proceeds restricted for construction
|
—
|
|
245
|
|
—
|
|
245
|
|
—
|
|
212
|
|
—
|
|
212
|
|
|||||||||||||||
|
Other - net
|
(668
|
)
|
20
|
|
626
|
|
(22
|
)
|
—
|
|
(59
|
)
|
(70
|
)
|
(129
|
)
|
|||||||||||||||
|
Net cash used in investing activities
|
(668
|
)
|
(2,015
|
)
|
(1,583
|
)
|
(4,266
|
)
|
(240
|
)
|
(3,234
|
)
|
(3,027
|
)
|
(6,501
|
)
|
|||||||||||||||
|
CASH FLOWS FROM FINANCING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
|
Issuances of long-term debt
|
—
|
|
3,155
|
|
498
|
|
3,653
|
|
—
|
|
3,632
|
|
594
|
|
4,226
|
|
|||||||||||||||
|
Retirements of long-term debt
|
—
|
|
(1,216
|
)
|
(453
|
)
|
(1,669
|
)
|
—
|
|
(1,272
|
)
|
(49
|
)
|
(1,321
|
)
|
|||||||||||||||
|
Proceeds from sale of differential membership interests
|
—
|
|
201
|
|
—
|
|
201
|
|
—
|
|
414
|
|
—
|
|
414
|
|
|||||||||||||||
|
Net change in short-term debt
|
—
|
|
(971
|
)
|
476
|
|
(495
|
)
|
—
|
|
254
|
|
142
|
|
396
|
|
|||||||||||||||
|
Issuances of common stock
|
415
|
|
—
|
|
—
|
|
415
|
|
386
|
|
—
|
|
—
|
|
386
|
|
|||||||||||||||
|
Dividends on common stock
|
(836
|
)
|
—
|
|
—
|
|
(836
|
)
|
(752
|
)
|
—
|
|
—
|
|
(752
|
)
|
|||||||||||||||
|
Other - net
|
(86
|
)
|
569
|
|
(647
|
)
|
(164
|
)
|
(56
|
)
|
(785
|
)
|
705
|
|
(136
|
)
|
|||||||||||||||
|
Net cash provided by (used in) financing activities
|
(507
|
)
|
1,738
|
|
(126
|
)
|
1,105
|
|
(422
|
)
|
2,243
|
|
1,392
|
|
3,213
|
|
|||||||||||||||
|
Net increase (decrease) in cash and cash equivalents
|
(1
|
)
|
217
|
|
13
|
|
229
|
|
—
|
|
(113
|
)
|
(18
|
)
|
(131
|
)
|
|||||||||||||||
|
Cash and cash equivalents at beginning of period
|
2
|
|
287
|
|
40
|
|
329
|
|
1
|
|
339
|
|
37
|
|
377
|
|
|||||||||||||||
|
Cash and cash equivalents at end of period
|
$
|
1
|
|
$
|
504
|
|
$
|
53
|
|
$
|
558
|
|
$
|
1
|
|
$
|
226
|
|
$
|
19
|
|
$
|
246
|
|
|||||||
————————————
|
(a)
|
Represents FPL and consolidating adjustments.
|
38
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 (loss)
and earnings (loss) per share by reportable segment - FPL, NEER and
Corporate and Other, which is primarily comprised of the operating results of NEET, FPL FiberNet and other business activities, as well as other income and expense items, including interest expense, income taxes and eliminating entries (
see Note 11
for additional segment information).
The discussion that follows should be read in conjunction with the Notes contained herein
and Management's Discussion and Analysis of Financial Condition and Results of Operations (Management's Discussion) appearing in the 2012 Form 10-K.
The results of operations for an interim period generally will not give a true indication of results for the year.
In the following discussion, all comparisons are with the corresponding items in the prior year period.
|
Net Income (Loss)
|
Earnings (Loss)
Per Share,
assuming dilution
|
Net Income (Loss)
|
Earnings (Loss)
Per Share,
assuming dilution
|
||||||||||||||||||||||||||||
|
Three Months Ended September 30,
|
Nine Months Ended September 30,
|
||||||||||||||||||||||||||||||
|
2013
|
2012
|
2013
|
2012
|
2013
|
2012
|
2013
|
2012
|
||||||||||||||||||||||||
|
(millions)
|
(millions)
|
||||||||||||||||||||||||||||||
|
FPL
|
$
|
422
|
|
$
|
392
|
|
$
|
0.99
|
|
$
|
0.93
|
|
$
|
1,101
|
|
$
|
984
|
|
$
|
2.59
|
|
$
|
2.35
|
|
|||||||
|
NEER
(a)
|
281
|
|
44
|
|
0.66
|
|
0.10
|
|
470
|
|
516
|
|
1.11
|
|
1.23
|
|
|||||||||||||||
|
Corporate and Other
|
(5
|
)
|
(21
|
)
|
(0.01
|
)
|
(0.05
|
)
|
10
|
|
(18
|
)
|
0.02
|
|
(0.03
|
)
|
|||||||||||||||
|
NEE
|
$
|
698
|
|
$
|
415
|
|
$
|
1.64
|
|
$
|
0.98
|
|
$
|
1,581
|
|
$
|
1,482
|
|
$
|
3.72
|
|
$
|
3.55
|
|
|||||||
______________________
|
(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.
|
Additional Outlook Matters
In addition to the initiatives described in the 2012 Form 10-K, investing in additional capital projects and improving other operations and maintenance (O&M) efficiency and productivity could provide incremental growth opportunities for NEE and FPL through 2016 as follows:
|
•
|
NEE, through its subsidiaries, may have the potential to deploy additional growth capital through 2016.
FPL has identified potential incremental capital expenditures that have the potential to improve its long-term customer value proposition and create value for NEE shareholders.
NEER expects to invest capital for additional U.S. wind projects with generation up to 1,500 MW in 2013 and 2014 and potential incremental capital for solar projects with generation up to 300 MW through 2016. NEER also expects to deploy approximately $200 million to $250 million per year of net capital in its gas infrastructure business through 2016.
|
|
•
|
NEET is actively competing for new transmission projects throughout North America.
|
|
•
|
For much of 2013, NEE and its subsidiaries have been engaged in an initiative to improve productivity, reduce O&M costs and seek additional growth opportunities (cost savings initiative). NEE expects the transition costs associated with the cost savings initiative for 2013 to range from approximately $65 million to $75 million
,
of which $46 million ($28 million after-tax) has been recorded through September 30, 2013.
|
Also see Note 10 - Commitments and - Contracts
.
Adjusted Earnings
NEE prepares its financial statements in accordance with generally accepted accounting principles in the U.S. (GAAP). However, management uses earnings excluding certain items (adjusted earnings), a non-GAAP financial measure, internally for financial planning, for analysis of performance, for reporting of results to the Board of Directors and as an input in determining 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.
39
Adjusted earnings exclude the unrealized mark-to-market effect of non-qualifying hedges (as described below) and other than temporary impairment (OTTI) losses on securities held in NEER’s nuclear decommissioning funds, net of the reversal of previously recognized OTTI losses on securities sold and losses on securities where price recovery was deemed unlikely (collectively, OTTI reversals). However, other adjustments may be made from time to time with the intent to provide more meaningful and comparable results of ongoing operations.
NEE and NEER segregate into two categories unrealized mark-to-market gains and losses on derivative transactions.
The first category, referred to as non-qualifying hedges, represents certain energy derivative transactions, and, beginning in the second quarter of 2013 certain interest rate derivative transactions, entered into as economic hedges but the transactions do not meet the requirements for hedge accounting, hedge accounting treatment is not elected or hedge accounting has been discontinued. Changes in the fair value of those transactions are marked to market and reported in the consolidated statements of income, resulting in earnings volatility because the economic offset to the positions are not marked to market.
As a consequence, NEE's net income reflects only the movement in one part of economically-linked transactions. For example, a gain (loss) in the non-qualifying hedge category for certain energy derivatives is offset by decreases (increases) in the fair value of related physical asset positions in the portfolio or contracts, which are not marked to market under GAAP.
For this reason, NEE's management views results expressed excluding the unrealized mark-to-market impact of the non-qualifying hedges as a meaningful measure of current period performance. The second category, referred to as trading activities, which is included in adjusted earnings, represents the net unrealized effect of actively traded positions entered into to take advantage of expected market price movements and all other commodity hedging activities. At FPL, substantially all changes in the fair value of energy derivative transactions are deferred as a regulatory asset or liability until the contracts are settled, and, upon settlement, any gains or losses are passed through the fuel clause or the capacity clause.
See Note
2.
During the
nine months ended September 30, 2013
, an after-tax net gain from discontinued operations of $188 million ($175 million recorded at NEER and $13 million recorded at Corporate and Other) was recorded in NEE's condensed consolidated statements of income. The after-tax net gain from discontinued operations consisted of $231 million for the March 2013 hydro sale, partly offset by a $43 million write down associated with Maine fossil. See Note 6. During the same period, an impairment charge recorded by NEER of $300 million ($342 million after-tax) related to the Spain solar projects was recorded in NEE's condensed consolidated statements of income. See Note 3 - Nonrecurring Fair Value Measurements and Note 5 and, for a discussion of additional developments that could potentially impact the Spain solar projects, see Note 10 - Spain Solar Projects. In order to make period to period comparisons more meaningful,
in 2013 adjusted earnings also exc
lude the after-tax net gain from discontinued operations, the after-tax charges associated with the impairment of the Spain solar projects and, beginning in the third quarter of 2013, the after-tax operating results associated with the Spain solar projects.
The following table provides details of the adjustments to net income considered in computing NEE's adjusted earnings discussed above.
|
Three Months Ended September 30,
|
Nine Months Ended September 30,
|
||||||||||||||||
|
2013
|
2012
|
2013
|
2012
|
||||||||||||||
|
(millions)
|
|||||||||||||||||
|
Net unrealized mark-to-market after-tax gains (losses) from non-qualifying hedge activity
(a)
|
$
|
76
|
$
|
(130
|
)
|
$
|
15
|
|
$
|
(28
|
)
|
||||||
|
Income (loss) from OTTI after-tax losses on securities held in NEER's nuclear decommissioning funds, net of OTTI reversals
|
$
|
—
|
$
|
13
|
$
|
1
|
|
$
|
30
|
|
|||||||
|
After-tax net gain from discontinued operations
(b)
|
$
|
—
|
$
|
—
|
$
|
188
|
|
$
|
—
|
|
|||||||
|
After-tax charges recorded by NEER associated with the impairment of the Spain solar projects
|
$
|
—
|
$
|
—
|
$
|
(342
|
)
|
$
|
—
|
|
|||||||
|
After-tax operating results of NEER's Spain solar projects
|
$
|
15
|
$
|
—
|
$
|
15
|
|
$
|
—
|
|
|||||||
____________________
|
(a)
|
All of the gains reported for the
three and nine months ended September 30, 2013
are included in NEER's net income. For the
three and nine months ended September 30, 2012
, $131 million and $31 million of losses, respectively, are included in NEER's net income; the balance is included in Corporate and Other.
|
|
(b)
|
For the
nine months ended September 30, 2013
, $175 million of the gain is included in NEER's net income; the balance is included in Corporate and Other.
|
The change in unrealized mark-to-market activity from non-qualifying hedges is primarily attributable to changes in forward power and natural gas prices and interest rates, as well as the reversal of previously recognized unrealized mark-to-market gains or losses as the underlying transactions were realized.
40
RESULTS OF OPERATIONS
Summary
NEE's net income for the
three months ended September 30, 2013
was higher than the prior period by $283 million, or 66 cents per share, primarily due to higher results at NEER. NEE's net income for the
nine months ended September 30, 2013
was higher than the prior period by $99 million, or 17 cents per share, primarily due to higher results at FPL.
FPL's increase in net income for the
three and nine months ended September 30, 2013
was primarily driven by continued investments in plant in service
which resulted in earning an 11.07% return on common equity as determined for regulatory purposes (regulatory ROE) on its retail rate base.
NEER's results increased for the
three months ended September 30, 2013
prima
rily due to net unrealized mark-to-market gains from non-qualifying hedge activity for the
three months ended September 30, 2013
compared to losses on such hedges in the prior year period and higher results from new investments.
NEER's results decreased for the
nine months ended September 30, 2013
prima
rily due to the $342 million of after-tax charges associated with the impairment of the Spain solar projects recorded in the first quarter of 2013, partly offset by the $175 million net after-tax gain from discontinued operations recorded in the first quarter of 2013 and higher results from new investments.
Corporate and Other's results improved for the
three and nine months ended September 30, 2013
primarily due to
the absence of a $13 million after-tax charge recorded in the third quarter of 2012 associated with an early stage technology investment and higher results from NEET, partly offset by higher interest expense.
NEE's effective income tax rates for the
three months ended September 30, 2013 and 2012
were approximately
30%
and
27%
, respectively. NEE's effective income tax rates for the
nine months ended September 30, 2013 and 2012
were approximately
33%
and
27%
, respectively. The increase in the rate for the
nine months ended September 30, 2013
is primarily due to the establishment of a full valuation allowance during the first quarter of 2013 on the deferred tax assets associated with the Spain solar projects (see Note 3 - Nonrecurring Fair Value Measurements and Note 5). The rates for all periods reflect the effect of PTCs for wind projects at NEER and deferred income tax benefits associated with convertible ITCs under the Recovery Act.
PTCs and deferred income tax benefits associated with convertible ITCs can significantly affect NEE's effective income tax rate depending on the amount of pretax income.
The amount of PTCs recognized can be significantly affected by wind generation and by PTC roll off.
PTCs for the
three months ended September 30, 2013 and 2012
were approximately $
36 million
and $
35 million
, respectively, and $
161 million
and $
147 million
for the comparable nine-month periods. Deferred income tax benefits associated with convertible ITCs for the
three months ended September 30, 2013 and 2012
were approximately $
29 million
and $
14 million
, respectively, and $
62 million
and $
37 million
for the comparable nine-month periods. See Note 5.
FPL: Results of Operations
FPL’s net income for the
three months ended September 30, 2013 and 2012
was $422 million and $392 million, respectively, an increase of $30 million. FPL’s net income for the
nine months ended September 30, 2013 and 2012
was $1,101 million and $984 million, respectively, an increase of $117 million.
The use of the reserve amortization is permitted by a January 2013 FPSC final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2012 rate agreement) and, for the prior period, a February
2011 FPSC final order approving a stipulation and settlement agreement between FPL and principal parties in a prior rate case (2010 rate agreement), subject to limitations provided in the rate agreements.
In order to earn a targeted regulatory ROE in each reporting period under the 2012 and 2010 rate agreements, reserve amortization is calculated using a trailing thirteen-month average of retail rate base and capital structure in conjunction with the trailing twelve months regulatory retail base net operating income, which primarily includes the retail base portion of base and other revenues, net of O&M, depreciation and amortization, interest, taxes other than income taxes and income tax expenses. In general, the net impact of these income statement line items are offset, in part, by reserve amortization to earn a targeted regulatory ROE. In certain periods, reserve amortization must be reversed so as not to exceed the targeted regulatory ROE. The drivers of FPL
'
s net income not reflected in the reserve amortization calculation include wholesale and transmission service revenues and expenses, cost recovery clause revenues and expenses, equity component of AFUDC (AFUDC - equity) and costs not allowed to be recovered by the FPSC.
FPL's regulatory ROE for the period ending September 30, 2013 was 11.07% compared to 11.0% in the prior year period. The 2013 regulatory ROE of 11.07% reflects approximately $19 million of after-tax charges associated with the cost savings initiative (see Overview - Additional Outlook Matters). These charges were not offset by additional reserve amortization.
Excluding the impact of these charges, FPL's regulatory ROE would have been approximately 11.25%. The $30 million and $117 million increase in FPL's net income for the
three and nine months ended September 30, 2013
, respectively, was primarily driven by:
|
•
|
higher earnings on investment in plant in service of $44 million and $133 million, respectively. Average investment in plant in service grew FPL's retail rate base by approximately $3.6 billion and $3.4 billion for the
three and nine months ended September 30, 2013
, respectively, reflecting, among other things, the extended power uprates at FPL's nuclear units, the
modernized Cape Canaveral facility (Cape Canaveral unit) and ongoing transmission and distribution additions, and
|
41
|
•
|
the increase in the regulatory ROE from 11.0% to 11.07%,
|
partly offset by,
|
•
|
lower cost recovery clause results of $13 million and $28 million, respectively, primarily due to the transfer of new nuclear capacity to retail rate base as discussed below under Retail Base and Cost Recovery Clauses.
|
In addition, FPL's results for the
nine months ended September 30, 2013
included higher AFUDC - equity of $6 million.
FPL's operating revenues consisted of the following:
|
Three Months Ended September 30,
|
Nine Months Ended September 30,
|
||||||||||||||
|
2013
|
2012
|
2013
|
2012
|
||||||||||||
|
(millions)
|
|||||||||||||||
|
Retail base
|
$
|
1,429
|
|
$
|
1,243
|
|
$
|
3,739
|
|
$
|
3,264
|
|
|||
|
Fuel cost recovery
|
976
|
|
1,131
|
|
2,523
|
|
2,916
|
|
|||||||
|
Net recognition of previously deferred retail fuel revenues
|
—
|
|
—
|
|
44
|
|
—
|
|
|||||||
|
Other cost recovery clauses and pass-through costs, net of any deferrals
|
542
|
|
536
|
|
1,389
|
|
1,416
|
|
|||||||
|
Other, primarily wholesale and transmission sales, customer-related fees and pole attachment rentals
|
73
|
|
65
|
|
210
|
|
182
|
|
|||||||
|
Total
|
$
|
3,020
|
|
$
|
2,975
|
|
$
|
7,905
|
|
$
|
7,778
|
|
|||
Retail Base
Included in retail base revenues for the
three and nine months ended September 30, 2013
were approximately $87 million and $234 million, respectively, of revenues associated with new retail base rates under the 2012 rate agreement. Additional retail base revenues of approximately $70 million and $182 million were collected during the
three and nine months ended September 30, 2013
, respectively, related to new nuclear capacity of approximately 365 MW, which was placed in service in 2012, as permitted by the FPSC's nuclear cost recovery rule. Retail base rates are expected to increase approximately $164 million on an annualized basis beginning on April 24, 2013 with the entry into service of the Cape Canaveral unit; additional retail base revenues related to the Cape Canaveral unit amounted to $48 million and $88 million for the
three and nine months ended September 30, 2013
, respectively.
FPSC Rate Orders
On September 19, 2013, the Florida Supreme Court heard oral argument on the State of Florida Office of Public Counsel's appeal of the FPSC's final order regarding the 2012 rate agreement. A ruling by the Florida Supreme Court is pending.
Retail Customer Usage and Growth
For the
three months ended September 30, 2013
, FPL experienced a 0.6% decline in retail sales, primarily due to weather conditions and increased efficiency measures, partly offset by retail customer growth and a slight improvement in the Florida economy, which collectively decreased retail base revenues by approximately $19 million. For the
nine months ended September 30, 2013
, FPL experienced a 0.9% decrease in retail sales, reflecting a reduction in usage per retail customer as a result of weather conditions, increased efficiency measures and one less day of sales in 2013, as 2012 was a leap year, partly offset by retail customer growth and a slight improvement in the Florida economy, which collectively decreased retail base revenues by approximately $29 million.
In the first quarter of 2013, FPL entered into an agreement to acquire the City of Vero Beach's electric utility system, which acquisition is subject to regulatory approvals and certain other conditions. FPL is targeting a late 2014 closing for the transaction and, upon closing, expects to add approximately 34,000 customer accounts.
42
Cost Recovery Clauses
Revenues from fuel and other cost recovery clauses and pass-through costs, such as franchise fees, revenue taxes and storm-related surcharges, are largely a pass-through of costs. Such revenues also include a return on investment allowed to be recovered through the cost recovery clauses on certain assets, primarily related to nuclear capacity, solar and environmental projects. For the
three months ended September 30, 2013 and 2012
,
cost recovery clauses contributed $29 million and $42 million, respectively, to FPL’s net income; the amounts for the
nine months ended September 30, 2013 and 2012
were $85 million and $113 million, respectively. The decreases are 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 condensed consolidated statements of income, as well as by changes in energy sales. Fluctuations in revenues from other cost recovery clauses and pass-through costs are primarily driven by changes in storm-related surcharges, capacity charges, franchise fee costs, the impact of changes in O&M and depreciation expenses on the underlying cost recovery clause, investment in solar and environmental projects, investment in nuclear capacity until such capacity goes into service and is recovered in base rates, pre-construction costs associated with the development of two additional nuclear units at the Turkey Point site and changes in energy sales. Capacity charges and franchise fee costs are included in fuel, purchased power and interchange and taxes other than income taxes and other, respectively, in the condensed consolidated statements of income. The decrease in fuel cost recovery revenues f
or the
three and nine months ended September 30, 2013
is primarily due to a lower average fuel factor, partly offset by gas sales associated with an incentive mechanism allowed under the 2012 rate agreement (incentive gas sales) and higher interchange power sales.
Other
FPL expects revenues from wholesale sales to increase approximately $100 million in 2014 primarily due to growth of load served under existing wholesale contracts.
Other Items Impacting FPL's Condensed Consolidated Statements of Income
Fuel, Purchased Power and Interchange
The major components of FPL's fuel, purchased power and interchange expense are as follows:
|
Three Months Ended September 30,
|
Nine Months Ended September 30,
|
||||||||||||||||
|
2013
|
2012
|
2013
|
2012
|
||||||||||||||
|
(millions)
|
|||||||||||||||||
|
Fuel and energy charges during the period
|
$
|
987
|
$
|
1,117
|
$
|
2,668
|
|
$
|
2,805
|
|
|||||||
|
Net recognition of previously deferred retail fuel costs
|
—
|
9
|
—
|
|
101
|
|
|||||||||||
|
Net deferral of retail fuel costs
|
(16
|
)
|
—
|
(107
|
)
|
—
|
|
||||||||||
|
Other, primarily capacity charges, net of any capacity deferral
|
170
|
154
|
418
|
|
395
|
|
|||||||||||
|
Total
|
$
|
1,141
|
$
|
1,280
|
$
|
2,979
|
|
$
|
3,301
|
|
|||||||
The decrease in fuel and energy charges for the
three and nine months ended September 30, 2013
was primarily due to lower fuel and energy prices, reflecting additional nuclear generation in 2013, which has a lower fuel cost, partly offset by gas purchased for incentive gas sales. The additional nuclear generation in 2013 was primarily due to increased capacity of the nuclear units as a result of the nuclear uprate project and higher nuclear production reflecting lower outage duration in 2013.
O&M Expenses
FPL's O&M expenses increased
$16 million for the
three months ended September 30, 2013
primarily due to approximately $23 million of cost savings initiative costs, partly offset by lower costs recoverable through cost recovery clauses, which are essentially pass-through costs. FPL's O&M expenses decreased $51 million for the
nine months ended September 30, 2013
, reflecting lower cost recovery clause costs of $42 million, the absence of nuclear outage costs incurred during an outage in the prior year and lower fossil outage costs primarily due to outage timing, partly offset by $31 million of cost savings initiative costs.
43
Depreciation and Amortization Expense
The major components of FPL’s depreciation and amortization expense are as follows:
|
Three Months Ended September 30,
|
Nine Months Ended September 30,
|
||||||||||||||
|
2013
|
2012
|
2013
|
2012
|
||||||||||||
|
(millions)
|
|||||||||||||||
|
Reserve reversal (amortization) recorded under the 2012 and 2010 rate agreements, respectively
|
$
|
10
|
|
$
|
(33
|
)
|
$
|
(208
|
)
|
$
|
(363
|
)
|
|||
|
Other depreciation and amortization recovered under base rates
|
279
|
|
254
|
|
824
|
|
756
|
|
|||||||
|
Depreciation and amortization recovered under cost recovery clauses and securitized storm-recovery cost amortization
|
62
|
|
33
|
|
164
|
|
103
|
|
|||||||
|
Total
|
$
|
351
|
|
$
|
254
|
|
$
|
780
|
|
$
|
496
|
|
|||
In the three months ended September 30, 2013, reserve amortization was reversed so as not to exceed the targeted retail regulatory ROE. Reserve amortization did not offset the 2013 charges associated with the cost savings initiative. The reserve reversal (amortization) recorded in the current periods was lower than amortization recorded in the prior year periods primarily due to additional base revenues collected in 2013 associated with new retail base rates under the 2012 rate agreement.
The reserve reversal (amortization) recorded for the
three and nine months ended September 30, 2013
under the 2012 rate agreement reflects the amortization of a depreciation reserve remaining at the end of 2012 under the 2010 rate order; at
September 30, 2013
approximately $16 million of this reserve remains available for future amortization. Also, FPL may amortize over the term of the 2012 rate agreement a portion of FPL's fossil dismantlement reserve up to a maximum of $176 million, subject to certain limits. Beginning in 2013, such amounts are being amortized as a reduction of regulatory liabilities - accrued asset removal costs on the condensed consolidated balance sheets. The increase in other depreciation and amortization expense recovered under base rates for the
three and nine months ended September 30, 2013
is primarily due to higher plant in service balances.
The increase in depreciation and amortization recovered under cost recovery clauses and securitized storm-recovery cost amortization for the
three and nine months ended September 30, 2013
is primarily due to recoveries of prior year investment under the FPSC's nuclear cost recovery rule and higher plant in service balances associated with environmental projects under the environmental cost recovery clause
.
Taxes Other Than Income Taxes and Other
Taxes other than income taxes and other increased $12 million and $33 million for the
three and nine months ended September 30, 2013
, respectively, primarily due to higher property taxes reflecting growth in plant in service balances and, also for the
nine months ended September 30, 2013
, higher payroll taxes, partly offset by lower franchise fees and revenue taxes, both of which are pass-through costs.
Interest Expense
The decrease in interest expense for the
nine months ended September 30, 2013
is primarily due to lower average interest rates and a higher debt component of AFUDC (AFUDC - debt), partly offset by higher average debt balances. The change in AFUDC - debt is due to the same factors as described below in AFUDC - equity.
AFUDC - Equity
The decrease in AFUDC - equity
for the
three months ended September 30, 2013
is primarily due to lower AFUDC - equity associated with the Cape Canaveral unit which was placed in service in April 2013, partly offset by additional AFUDC - equity recorded on construction expenditures associated with the Riviera Beach and Port Everglades modernization projects. The increase in AFUDC - equity
for the
nine months ended September 30, 2013
is primarily due to additional AFUDC - equity recorded on construction expenditures associated with the Riviera Beach and Port Everglades modernization projects, partly offset by lower AFUDC - equity associated with the Cape Canaveral unit.
Major Capital Projects
In April 2013, FPL completed the final stage of its generation uprate project at Turkey Point Unit No. 4 and placed in service the approximately 1,210 MW natural gas-fired combined-cycle Cape Canaveral unit. In October 2013, the Florida Supreme Court dismissed the Florida Industrial Power Users Group’s appeal of the FPSC’s order approving FPL’s Port Everglades modernization.
44
NEER: Results of Operations
NEER’s net income for
the
three months ended September 30, 2013 and 2012
was $281 million and $44 million, respectively, an increase of $237 million. NEER’s net income for
the
nine months ended September 30, 2013 and 2012
was $470 million and $516 million, respectively, a decrease of $46 million. The primary drivers, on an after-tax basis, of these changes are in the following table. The 99.8 MW associated with the
Spain solar projects
and the related operating results are not included in new investments data below.
|
Increase (Decrease)
From Prior Period
|
|||||||
|
Three Months Ended September 30, 2013
|
Nine Months Ended
September 30, 2013 |
||||||
|
(millions)
|
|||||||
|
New investments
(a)
|
$
|
33
|
|
$
|
99
|
|
|
|
Existing assets
(a)
|
—
|
|
(5
|
)
|
|||
|
Gas infrastructure
(b)
|
9
|
|
7
|
|
|||
|
Customer supply and proprietary power and gas trading businesses
(b)
|
(13
|
)
|
(5
|
)
|
|||
|
Interest expense, differential membership costs and other
|
(1
|
)
|
(7
|
)
|
|||
|
Change in unrealized mark-to-market non-qualifying hedge activity
(c)(d)
|
207
|
|
46
|
|
|||
|
Change in OTTI losses on securities held in nuclear decommissioning funds, net of OTTI reversals
(d)
|
(13
|
)
|
(29
|
)
|
|||
|
Net gain from discontinued operations
(e)
|
—
|
|
175
|
|
|||
|
Charges associated with the impairment of the Spain solar projects
(f)
|
—
|
|
(342
|
)
|
|||
|
Operating results of the Spain solar projects
(f)
|
15
|
|
15
|
|
|||
|
Net income increase (decrease)
|
$
|
237
|
|
$
|
(46
|
)
|
|
______________________
|
(a)
|
Includes PTCs and state ITCs on wind projects and, for new investments, deferred income tax and other benefits associated with convertible ITCs but does not include allocation of interest expense or corporate general and administrative expenses. Results from new projects are included in new investments during the first twelve months of operation. A project's results are included in existing assets beginning with the thirteenth month of operation.
|
|
(b)
|
Does not include allocation of interest expense or corporate general and administrative expenses.
|
|
(c)
|
See Note 2 and Overview related to derivative instruments.
|
|
(d)
|
See table in Overview for additional detail.
|
|
(e)
|
See Note 6 and Overview for additional information
.
|
|
(f)
|
See Note 3 - Nonrecurring Fair Value Measurements and Overview - Adjusted Earnings for additional information.
|
New Investments
Results from new investments
for the
three months ended September 30, 2013
increased primarily due to:
|
•
|
the addition of approximately 1,343 MW of wind generation during or after the
three months ended September 30, 2012
, and
|
|
•
|
higher deferred income tax and other benefits associated with convertible ITCs of $15 million,
|
partly offset by,
|
•
|
lower stat
e ITCs of $4 million.
|
Results from new investments
for the
nine months ended September 30, 2013
increased primarily due to:
|
•
|
the addition of approximately 1,520 MW of wind and 40 MW of solar generation during or after the
nine months ended September 30, 2012
, and
|
|
•
|
higher deferred income tax and other benefits associated with convertible ITCs of $15 million,
|
partly offset by,
|
•
|
lower stat
e ITCs of $7 million.
|
Existing Assets
Results from NEER's existing asset portfolio for the
nine months ended September 30, 2013
decreased primarily due to:
|
•
|
lower wind generation of approximately $25 million,
|
|
•
|
PTC roll off of $14 million, and
|
|
•
|
lower results of $13 million due to the absence of the hydro assets which were sold in the first quarter of 2013,
|
partly offset by,
|
•
|
increased generation at Seabrook, primarily due to the absence of a 2012 reduction in capacity, as well as lower operating costs at that facility, and
|
45
|
•
|
improved results of $7 million in the Electric Reliability Council of Texas (ERCOT) region, primarily due to the absence of outages that occurred in 2012 at the natural gas facilities, and favorable market conditions.
|
Gas Infrastructure
The increase in gas infrastructure results for the
three and nine months ended September 30, 2013
is primarily due to income from additional production in 2013, partly offset for the
nine months ended September 30, 2013
by the absence of gains recorded in the first quarter of 2012 from exiting the hedged positions on a number of future gas production opportunities.
Customer Supply and Proprietary Power and Gas Trading
Results from the customer supply and proprietary power and gas trading businesses decreased
for the
three and nine months ended September 30, 2013
primarily due to lower results in the customer supply business reflecting lower margins and mild weather conditions, partly offset by higher power and gas trading results.
Interest Expense, Differential Membership Costs and Other
For the
three and nine months ended September 30, 2013
, interest expense, differential membership costs and other reflects higher borrowing and other costs to support the growth of the business and cost savings initiative costs, partly offset by lower average interest rates and favorable income tax benefits.
Other Factors
Supplemental to the primary drivers of the changes in net income discussed above, the discussion below describes changes in certain line items set forth in NEE's condensed consolidated statements of income as they relate to NEER.
Operating Revenues
Operating revenues for the
three months ended September 30, 2013
increased
$473 million primarily due to:
|
•
|
higher unrealized mark-to-market gains from non-qualifying hedges ($94 million for the
three months ended September 30, 2013
compared to $161 million of losses on such hedges for the comparable period in 2012),
|
|
•
|
higher revenues in the New England Power Pool (NEPOOL) region primarily due to higher generation at Seabrook due to the absence of a 2012 reduction in capacity, higher revenues in the ERCOT region and higher gas infrastructure revenues, partly offset by lower customer supply and proprietary power and gas trading revenues (collectively, $119 million), and
|
|
•
|
higher revenues from new investments of approximately $88 million, including $43 million associated with the Spain solar projects.
|
Operating revenues for the
nine months ended September 30, 2013
increased $414 million primarily due to:
|
•
|
higher revenues in the NEPOOL region primarily due to higher generation at Seabrook due to the absence of a 2012 reduction in capacity, higher gas infrastructure revenues and higher revenues in the ERCOT region primarily due to the absence of outages that occurred in 2012 at the natural gas facilities, offset in part by lower customer supply and proprietary power and gas trading revenues (collectively, $340 million), and
|
|
•
|
higher revenues from new investments of approximately $200 million, including $43 million associated with the Spain solar projects,
|
partly offset by,
|
•
|
lower wind generation from the existing asset portfolio, and
|
|
•
|
higher unrealized mark-to-market losses from non-qualifying hedges ($13 million for the
nine months ended September 30, 2013
compared to $62 million of gains on such hedges for the comparable period in 2012).
|
Operating Expenses
Operating expenses for the
three months ended September 30, 2013
increased $111 million primarily due to:
|
•
|
higher fuel expense in the NEPOOL and ERCOT regions and higher gas infrastructure operating expenses (collectively, $154 million), and
|
|
•
|
higher operating expenses associated with new investments of approximately $44 million, including $13 million associated with the Spain solar projects,
|
partly offset by,
|
•
|
higher unrealized mark-to-market gains from non-qualifying hedges ($19 million for the
three months ended September 30, 2013
compared to $59 million of losses on such hedges for the comparable period in 2012).
|
46
Operating expenses for the
nine months ended September 30, 2013
increased $589 million primarily due to:
|
•
|
an impairment charge of $300 million related to the Spain solar projects,
|
|
•
|
higher fuel expense primarily in the NEPOOL and ERCOT regions and higher gas infrastructure operating expenses, offset in part by lower customer supply and proprietary power and gas trading fuel expense (collectively, $285 million),
and
|
|
•
|
higher operating expenses associated with new investments of approximately $109 million, including $13 million associated with the Spain solar projects,
|
partly offset by,
|
•
|
higher unrealized mark-to-market gains from non-qualifying hedges ($1 million for the
nine months ended September 30, 2013
compared to $120 million of losses on such hedges for the comparable period in 2012).
|
Interest Expense
NEER’s interest expense for
the
three and nine months ended September 30, 2013
increased $20 million and $4 million, respectively, primarily due to
higher average debt balances,
partly offset by lower average interest rates
. In addition,
NEER’s interest expense for
the
three and nine months ended September 30, 2013
reflect a $3 million and $14 million, respectively, favorable change in the fair value of cash flow hedges related to interest rate swaps for which hedge accounting was discontinued in the second quarter of 2013 (see Note 2 and Overview - Adjusted Earnings). NEER’s interest expense for
the
three and nine months ended September 30, 2013
also includes approximately $14 million of additional interest expense associated with the Spain solar projects, primarily due to the absence of capitalized interest in the current period as the project was placed in service in June 2013.
Benefits Associated with Differential Membership Interests - Net
Benefits associated with differential membership interests - net in NEE's condensed consolidated statements of income for
all periods presented
reflect benefits recognized by NEER as third-party investors received their portion of the economic attributes, including income tax attributes, of the underlying wind project, net of associated costs. For the
nine months ended September 30, 2012
, benefits associated with differential membership interests - net also includes $14 million of benefits where the investors elected to receive the convertible ITCs related to the underlying wind project; there were no such benefits for any other periods presented.
Gains on Disposal of Assets
-
Net
Gains on disposal of assets
-
net in NEE
'
s condensed consolidated statements of income for the
three and nine months ended September 30, 2013 and 2012
primarily reflect gains on sales of securities held in NEER
'
s nuclear decommissioning funds and, for these respective periods, include approximately $2 million, $13 million, $27 million and $62 million of OTTI reversals.
Tax Credits and Benefits
PTCs from NEER’s wind projects are reflected in NEER’s earnings. PTCs are recognized as wind energy is generated and sold based on a per kWh rate prescribed in applicable federal and state statutes. A portion of the PTCs have been allocated to investors in connection with the sales of differential membership interests. Also see Summary above and Note 5 for a discussion of PTCs and deferred income tax benefits associated with convertible ITCs and b
enefits associated with differential membership interests - net above
.
Corporate and Other: Results of Operations
Corporate and Other is primarily comprised of the operating results of NEET, FPL FiberNet and other business activities, as well as corporate interest income and expenses. Corporate and Other allocates non-utility interest expense and shared service costs to NEER. Interest expense is allocated based on a deemed capital structure of 70% debt and, for purposes of allocating non-utility interest expense, the liability associated with differential membership interests sold by NEER’s subsidiaries is included with debt. Each subsidiary’s income taxes are calculated based on the "separate return method," except that tax benefits that could not be used on a separate return basis, but are used on the consolidated tax return, are recorded by the subsidiary that generated the tax benefits. Any remaining consolidated income tax benefits or expenses are recorded at Corporate and Other. The major components of Corporate and Other’s results, on an after-tax basis, are as follows:
|
Three Months Ended September 30,
|
Nine Months Ended September 30,
|
||||||||||||||
|
2013
|
2012
|
2013
|
2012
|
||||||||||||
|
(millions)
|
|||||||||||||||
|
Interest expense, net of allocations to NEER
|
$
|
(29
|
)
|
$
|
(24
|
)
|
$
|
(87
|
)
|
$
|
(68
|
)
|
|||
|
Interest income
|
8
|
|
10
|
|
24
|
|
27
|
|
|||||||
|
Federal and state income tax benefits
|
7
|
|
4
|
|
26
|
|
18
|
|
|||||||
|
Other
|
9
|
|
(11
|
)
|
47
|
|
5
|
|
|||||||
|
Net income (loss)
|
$
|
(5
|
)
|
$
|
(21
|
)
|
$
|
10
|
|
$
|
(18
|
)
|
|||
47
The increase in interest expense, net of allocations to NEER, for the
three and nine months ended September 30, 2013
reflects higher average debt balances, partly offset by lower average interest rates. The federal and state income tax benefits for both periods reflect consolidating income tax adjustments and, for the
nine months ended September 30, 2013
, also include a $13 million
income tax benefit recorded as net gain from discontinued operations, net of federal income taxes, in NEE's condensed consolidated statements of income (see Overview - Adjusted Earnings and Note 6). Other includes all other corporate income and expenses, as well as other business activities. The increase for the
three and nine months ended September 30, 2013
reflects higher results from NEET and the absence of a $13 million after-tax impairment charge on an early stage technology investment recorded in the third quarter of 2012; the pretax amount ($20 million) of such impairment is reflected in other - net in NEE's condensed consolidated statements of income.
Transmission Project
In late March 2013, Lone Star achieved commercial operation of approximately 330 miles of new transmission lines and associated transmission facilities in Texas. Also see Part II, Item 5. (c)(ii) in the Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2013 for NEE and FPL.
LIQUIDITY AND CAPITAL RESOURCES
NEE and its subsidiaries, including FPL, require funds to support and grow their businesses. These funds are used for, among other things, working capital, capital expenditures, investments in or acquisitions of assets and businesses, payment of maturing debt obligations and, from time to time, redemption or repurchase of outstanding debt or equity securities. It is anticipated that these requirements will be satisfied through a combination of cash flow from operations, short- and long-term borrowings, and the issuance, from time to time, of short- and long-term debt and equity securities and proceeds from the sale of differential membership interests, consistent with NEE’s and FPL’s objective of maintaining, on a long-term basis, a capital structure that will support a strong investment grade credit rating.
NE
E, FPL and NEECH rely on access to credit and capital markets as significant sources of liquidity for capital requirements and other operations that are not satisfied by operating cash flows. The inability of NEE, FPL and NEECH to maintain their current credit ratings could affect their ability to raise short- and long-term capital, their cost of capital and the execution of their respective financing strategies, and could require the posting of additional collateral under certain agreements.
Cash Flows
Sources and uses of NEE's and FPL's cash for the
nine months ended September 30, 2013
and
2012
were as follows:
|
NEE
|
FPL
|
||||||||||||||
|
Nine Months Ended September 30,
|
Nine Months Ended September 30,
|
||||||||||||||
|
2013
|
2012
|
2013
|
2012
|
||||||||||||
|
(millions)
|
|||||||||||||||
|
Sources of cash:
|
|||||||||||||||
|
Cash flows from operating activities
|
$
|
3,390
|
|
$
|
3,157
|
|
$
|
2,792
|
|
$
|
2,302
|
|
|||
|
Long-term borrowings and change in loan proceeds restricted for construction
|
3,898
|
|
4,438
|
|
498
|
|
594
|
|
|||||||
|
Proceeds from the sale of differential membership interests - net of payments
|
154
|
|
361
|
|
—
|
|
—
|
|
|||||||
|
Capital contribution from NEE
|
—
|
|
—
|
|
—
|
|
240
|
|
|||||||
|
Cash grants under the Recovery Act
|
170
|
|
105
|
|
—
|
|
—
|
|
|||||||
|
Issuances of common stock - net
|
415
|
|
386
|
|
—
|
|
—
|
|
|||||||
|
Net increase in short-term debt
|
—
|
|
396
|
|
475
|
|
142
|
|
|||||||
|
Other sources - net
|
52
|
|
15
|
|
34
|
|
36
|
|
|||||||
|
Total sources of cash
|
8,079
|
|
8,858
|
|
3,799
|
|
3,314
|
|
|||||||
|
Uses of cash:
|
|||||||||||||||
|
Capital expenditures, independent power and other investments and nuclear fuel purchases
|
(4,659
|
)
|
(6,689
|
)
|
(2,209
|
)
|
(3,198
|
)
|
|||||||
|
Retirements of long-term debt
|
(1,669
|
)
|
(1,321
|
)
|
(453
|
)
|
(50
|
)
|
|||||||
|
Net decrease in short-term debt
|
(495
|
)
|
—
|
|
—
|
|
—
|
|
|||||||
|
Dividends
|
(836
|
)
|
(752
|
)
|
(1,070
|
)
|
—
|
|
|||||||
|
Repurchases of common stock
|
—
|
|
(19
|
)
|
—
|
|
—
|
|
|||||||
|
Other uses - net
|
(191
|
)
|
(208
|
)
|
(53
|
)
|
(82
|
)
|
|||||||
|
Total uses of cash
|
(7,850
|
)
|
(8,989
|
)
|
(3,785
|
)
|
(3,330
|
)
|
|||||||
|
Net increase (decrease) in cash and cash equivalents
|
$
|
229
|
|
$
|
(131
|
)
|
$
|
14
|
|
$
|
(16
|
)
|
|||
48
In the third quarter of 2013, NEE elected to post cash collateral with counterparties related to commodity contracts rather than use letters of credit which reduced cash flow from operations by approximately
$463 million
for the nine months ended September 30, 2013. The $463 million of cash collateral deposits are included in other current assets on the condensed consolidated balance sheet of NEE at September 30, 2013. NEE expects to return to using letters of credit for collateral posting in the fourth quarter of 2013. See Liquidity below.
NEE's primary capital requirements are for expanding and enhancing FPL's electric system and generating facilities to continue to provide reliable service to meet customer electricity demands and for funding NEER's investments in independent power and other projects. The following table provides a summary of the major capital investments for the
nine months ended September 30, 2013
and
2012
.
|
Nine Months Ended September 30,
|
|||||||
|
2013
|
2012
|
||||||
|
(millions)
|
|||||||
|
FPL:
|
|||||||
|
Generation:
|
|||||||
|
New
|
$
|
778
|
|
$
|
1,852
|
|
|
|
Existing
|
424
|
|
428
|
|
|||
|
Transmission and distribution
|
634
|
|
692
|
|
|||
|
Nuclear fuel
|
116
|
|
137
|
|
|||
|
General and other
|
115
|
|
57
|
|
|||
|
Other, primarily the exclusion of AFUDC - equity and change in accrued property additions
|
142
|
|
32
|
|
|||
|
Total
|
2,209
|
|
3,198
|
|
|||
|
NEER:
|
|||||||
|
Wind
|
864
|
|
1,498
|
|
|||
|
Solar
|
689
|
|
929
|
|
|||
|
Nuclear, including nuclear fuel
|
172
|
|
203
|
|
|||
|
Other
|
603
|
|
460
|
|
|||
|
Total
|
2,328
|
|
3,090
|
|
|||
|
Corporate and Other
|
122
|
|
401
|
|
|||
|
Total capital expenditures and independent power and other investments and nuclear fuel purchases
|
$
|
4,659
|
|
$
|
6,689
|
|
|
49
Liquidity
At
September 30, 2013
, NEE's total net available liquidity was approximately $
7.1 billion, of which FPL's portion was approximately $2.7 billion. The table below provides the components of FPL's and NEECH's ne
t available liquidity at
September 30, 2013
:
|
Maturity Date
|
|||||||||||||||
|
FPL
|
NEECH
|
Total
|
FPL
|
NEECH
|
|||||||||||
|
(millions)
|
|||||||||||||||
|
Bank revolving line of credit facilities
(a)
|
$
|
3,000
|
|
$
|
4,600
|
|
$
|
7,600
|
|
(b)
|
(b)
|
||||
|
Less letters of credit
|
(3
|
)
|
(573
|
)
|
(576
|
)
|
|||||||||
|
2,997
|
|
4,027
|
|
7,024
|
|
||||||||||
|
Revolving credit facility
|
235
|
|
—
|
|
235
|
|
2014
|
||||||||
|
Less borrowings
|
—
|
|
—
|
|
—
|
|
|||||||||
|
235
|
|
—
|
|
235
|
|
||||||||||
|
Letter of credit facilities
(c)
|
—
|
|
250
|
|
250
|
|
2015
|
||||||||
|
Less letters of credit
|
—
|
|
(71
|
)
|
(71
|
)
|
|||||||||
|
—
|
|
179
|
|
179
|
|
||||||||||
|
Subtotal
|
3,232
|
|
4,206
|
|
7,438
|
|
|||||||||
|
Cash and cash equivalents
|
54
|
|
504
|
|
558
|
|
|||||||||
|
Less commercial paper
|
(580
|
)
|
(335
|
)
|
(915
|
)
|
|||||||||
|
Net available liquidity
|
$
|
2,706
|
|
$
|
4,375
|
|
$
|
7,081
|
|
||||||
_______________________
|
(a)
|
Provide for the funding of loans up to $7,600 million ($3,000 million for FPL) and the issuance of letters of credit up to $6,600 million ($2,500 million for FPL). The entire amount of the credit facilities is available for general corporate purposes, including to provide back-up liquidity for FPL’s and NEECH’s respective commercial paper programs and other short-term borrowings and to provide additional liquidity in the event of a loss to the companies’ or their subsidiaries’ operating facilities (including, in the case of FPL, a transmission and distribution property loss). FPL’s bank revolving line of credit facilities are also available to support the purchase of $633 million of pollution control, solid waste disposal and industrial development revenue bonds (tax exempt bonds) in the event they are tendered by individual bond holders and not remarketed prior to maturity.
|
|
(b)
|
$500 million of NEECH
'
s and $500 million of FPL's bank revolving line of credit facilities expire in December 2013 and in 2016, respectively. Essentially all of the remaining facilities at each of FPL and NEECH expire in 2018.
|
|
(c)
|
Only available for the issuance of letters of credit.
|
Additionally, at
September 30, 2013
, certain subsidiaries of NEE had credit or loan facilities with available liquidity as set forth in the table below. In order for the applicable borrower to borrow or to have letters of credit issued under the terms of the agreements listed below, among other things, NEE's ratio of funded debt to total capitalization that is specified in the agreement may not be exceeded. These agreements also generally contain covenants and default and related acceleration provisions relating to, among other things, failure of NEE to maintain a ratio of funded debt to total capitalization at required levels. Some of the payment obligations of the borrowers under the agreements listed below ultimately are guaranteed by NEE.
|
Amount
|
Amount
Remaining
Available at
September 30, 2013
|
Rate
|
Maturity
Date
|
Related
Project Use
|
|||||
|
(millions)
|
|||||||||
|
NEECH and certain subsidiaries of NEER:
|
|||||||||
|
Canadian revolving credit agreements
(a)
|
C$750
|
$142
|
Variable
|
Various
|
Canadian renewable generating assets
|
||||
|
Revolving loan agreement
(b)
|
€161.5
|
$17
|
Variable
|
2014
|
Construction of Spain solar projects
|
||||
|
Certain subsidiaries of NEER:
|
|||||||||
|
Senior secured limited-recourse loan agreement
(b)
|
€589.2
|
$38
|
Variable
|
2030
|
Construction of Spain solar projects
|
||||
|
Term loan facility
|
$150
|
$88
|
Variable
|
2019
|
Construction of Genesis solar project
|
||||
______________________
|
(a)
|
Available for general corporate purposes; the current intent is to use these facilities for the purchase, development, construction, and/or operation of Canadian renewable generating assets. Consist of agreements with original amounts of C$150 million with a maturity date of December 2013, C$400 million with a maturity date of 2014, C$100 million with a maturity date of 2015, and C$100 million with a maturity date of 2016 with approximately $1 million, none, $97 million and $44 million, respectively, remaining available under these agreements at
September 30, 2013
.
|
|
(b)
|
See Note 10 - Spain Solar Projects for a discussion of the effect that a change in Spanish law has had on these financing agreements.
|
50
Capital Support
Letters of Credit, Surety Bonds and Guarantees
NEE and FPL obtain letters of credit and surety bonds and issue guarantees to facilitate commercial transactions with third parties and financings. Letters of credit, surety bonds and guarantees support, among other things, the buying and selling of wholesale energy commodities, debt and related reserves, capital expenditures for NEER's wind and solar development, nuclear activities and other contractual agreements.
Substantially all of NEE's and FPL's guarantee arrangements are on behalf of their consolidated subsidiaries for their related payment obligations.
In addition, as part of contract negotiations in the normal course of business, NEE and FPL may agree to make payments to compensate or indemnify other parties for possible future unfavorable financial consequences resulting from specified events. The specified events may include, but are not limited to, an adverse judgment in a lawsuit, the imposition of additional taxes due to a change in tax law or interpretations of the tax law or the non-receipt of renewable tax credits or proceeds from cash grants under the Recovery Act. NEE and FPL are unable to develop an estimate of the maximum potential amount of future payments under some of these contracts because events that would obligate them have not yet occurred or, if any such event has occurred, they have not been notified of its occurrence.
In addition, NEE has guaranteed certain payment obligations of NEECH, including most of its debt and all of its debentures and commercial paper issuances, as well as most of its payment guarantees and indemnifications, and NEECH has guaranteed certain debt and other obligations of NEER and its subsidiaries.
At
September 30, 2013
, NEE had approximately $721 million of standby letters of credit ($3 million for FPL), approximately $156 million of surety bonds ($21 million for FPL) and approximately $11.4 billion notional amount of guarantees and indemnifications ($18 million for FPL), of which approximately $5.9 billion of letters of credit, guarantees and indemnifications ($8 million for FPL) have expiration dates within the next five years.
Each of NEE and FPL believe it is unlikely that it would incur any liabilities associated with these letters of credit, surety bonds, guarantees and indemnifications. Accordingly, at
September 30, 2013
, NEE and FPL did not have any liabilities recorded for these letters of credit, surety bonds, guarantees and indemnifications.
Shelf Registration
In August 2012, NE
E, NEECH and FPL filed a shelf registration statement with the SEC for an unspecified amount of securities which became effective upon filing. The amount of securities issuable by the companies is established from time to time by their respective boards of directors. As of November 1, 2013, securities that may be issued under the registration statement include, depending on the registrant, senior debt securities, subordinated debt securities, junior subordinated debentures, first mortgage bonds, common stock, preferred stock, stock purchase contracts, stock purchase units, warrants and guarantees related to certain of those securities. As of November 1, 2013, the board-authorized capacity available to issue securities was approximately $4.0 billion for NEE and NEECH (issuable by either or both of them up to such aggregate amount) and $1.6 billion for FPL.
Energy Marketing and Trading and Market Risk Sensitivity
NEE and FPL are exposed to risks associated with adverse changes in commodity prices, interest rates, equity prices and currency exchange rates.
Financial instruments and positions affecting the financial statements of NEE and FPL described below are held primarily for purposes other than trading. Market risk is measured as the potential loss in fair value resulting from hypothetical reasonably possible changes in commodity prices, interest rates, equity prices or currency exchange rates over the next year.
Management has established risk management policies to monitor and manage such market risks, as well as credit risks.
Commodity Price Risk
NEE and FPL use derivative instruments (primarily swaps, options, futures and forwards) to manage the commodity price risk inherent in the purchase and sale of fuel and electricity. In addition, NEE, through NEER, uses derivatives to optimize the value of its power generation and gas infrastructure assets and engages in power and gas marketing and trading activities to take advantage of expected future favorable price movements. See Note 2.
51
The changes in the fair value of NEE's consolidated subsidiaries' energy contract derivative instruments for the
three and nine months ended September 30, 2013
were as follows:
|
|
|
Hedges on Owned Assets
|
|
||||||||||||
|
|
Trading
|
Non-
Qualifying
|
FPL Cost
Recovery
Clauses
|
NEE Total
|
|||||||||||
|
(millions)
|
|||||||||||||||
|
Three months ended September 30, 2013
|
|||||||||||||||
|
Fair value of contracts outstanding at June 30, 2013
|
$
|
296
|
|
$
|
546
|
|
$
|
(46
|
)
|
$
|
796
|
|
|||
|
Reclassification to realized at settlement of contracts
|
(6
|
)
|
15
|
|
7
|
|
16
|
|
|||||||
|
Net option premium purchases (issuances)
|
(3
|
)
|
6
|
|
—
|
|
3
|
|
|||||||
|
Changes in fair value excluding reclassification to realized
|
40
|
|
88
|
|
(22
|
)
|
106
|
|
|||||||
|
Fair value of contracts outstanding at September 30, 2013
|
327
|
|
655
|
|
(61
|
)
|
921
|
|
|||||||
|
Net margin cash collateral paid (received)
|
(178
|
)
|
|||||||||||||
|
Total mark-to-market energy contract net assets (liabilities) at September 30, 2013
|
$
|
327
|
|
$
|
655
|
|
$
|
(61
|
)
|
$
|
743
|
|
|||
|
|
|
Hedges on Owned Assets
|
|
||||||||||||
|
|
Trading
|
Non-
Qualifying
|
FPL Cost
Recovery
Clauses
|
NEE Total
|
|||||||||||
|
|
(millions)
|
||||||||||||||
|
Nine months ended September 30, 2013
|
|
|
|
|
|||||||||||
|
Fair value of contracts outstanding at December 31, 2012
|
$
|
261
|
|
$
|
674
|
|
$
|
(15
|
)
|
$
|
920
|
|
|||
|
Reclassification to realized at settlement of contracts
|
(15
|
)
|
(31
|
)
|
(19
|
)
|
(65
|
)
|
|||||||
|
Inception value of new contracts
|
3
|
|
—
|
|
—
|
|
3
|
|
|||||||
|
Net option premium purchases (issuances)
|
(19
|
)
|
(2
|
)
|
—
|
|
(21
|
)
|
|||||||
|
Changes in fair value excluding reclassification to realized
|
97
|
|
14
|
|
(27
|
)
|
84
|
|
|||||||
|
Fair value of contracts outstanding at September 30, 2013
|
327
|
|
655
|
|
(61
|
)
|
921
|
|
|||||||
|
Net margin cash collateral paid (received)
|
(178
|
)
|
|||||||||||||
|
Total mark-to-market energy contract net assets (liabilities) at September 30, 2013
|
$
|
327
|
|
$
|
655
|
|
$
|
(61
|
)
|
$
|
743
|
|
|||
NEE's total mark-to-market energy contract net assets (liabilities) at
September 30, 2013
shown above are included on the condensed consolidated balance sheets as follows:
|
|
September 30, 2013
|
||
|
|
(millions)
|
||
|
Current derivative assets
|
$
|
411
|
|
|
Noncurrent derivative assets
|
963
|
|
|
|
Current derivative liabilities
|
(361
|
)
|
|
|
Noncurrent derivative liabilities
|
(270
|
)
|
|
|
NEE's total mark-to-market energy contract net assets
|
$
|
743
|
|
52
The sources of fair value estimates and maturity of energy contract derivative instruments at
September 30, 2013
were as follows:
|
|
Maturity
|
|||||||||||||||||||||||||||
|
|
2013
|
2014
|
2015
|
2016
|
2017
|
Thereafter
|
Total
|
|||||||||||||||||||||
|
|
(millions)
|
|||||||||||||||||||||||||||
|
Trading:
|
||||||||||||||||||||||||||||
|
Quoted prices in active markets for identical assets
|
$
|
(10
|
)
|
$
|
34
|
|
$
|
15
|
|
$
|
(4
|
)
|
$
|
—
|
|
$
|
—
|
|
$
|
35
|
|
|||||||
|
Significant other observable inputs
|
12
|
|
18
|
|
14
|
|
29
|
|
22
|
|
(4
|
)
|
91
|
|
||||||||||||||
|
Significant unobservable inputs
|
7
|
|
41
|
|
41
|
|
42
|
|
35
|
|
35
|
|
201
|
|
||||||||||||||
|
Total
|
9
|
|
93
|
|
70
|
|
67
|
|
57
|
|
31
|
|
327
|
|
||||||||||||||
|
Owned Assets - Non-Qualifying:
|
|
|
|
|
|
|
|
|||||||||||||||||||||
|
Quoted prices in active markets for identical assets
|
1
|
|
(12
|
)
|
3
|
|
—
|
|
—
|
|
—
|
|
(8
|
)
|
||||||||||||||
|
Significant other observable inputs
|
—
|
|
39
|
|
30
|
|
63
|
|
11
|
|
7
|
|
150
|
|
||||||||||||||
|
Significant unobservable inputs
|
42
|
|
62
|
|
39
|
|
58
|
|
66
|
|
246
|
|
513
|
|
||||||||||||||
|
Total
|
43
|
|
89
|
|
72
|
|
121
|
|
77
|
|
253
|
|
655
|
|
||||||||||||||
|
Owned Assets - FPL Cost Recovery Clauses:
|
|
|
|
|
|
|
||||||||||||||||||||||
|
Quoted prices in active markets for identical assets
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
—
|
|
||||||||||||||
|
Significant other observable inputs
|
—
|
|
(62
|
)
|
—
|
|
—
|
|
—
|
|
—
|
|
(62
|
)
|
||||||||||||||
|
Significant unobservable inputs
|
—
|
|
1
|
|
—
|
|
—
|
|
—
|
|
—
|
|
1
|
|
||||||||||||||
|
Total
|
—
|
|
(61
|
)
|
—
|
|
—
|
|
—
|
|
—
|
|
(61
|
)
|
||||||||||||||
|
Total sources of fair value
|
$
|
52
|
|
$
|
121
|
|
$
|
142
|
|
$
|
188
|
|
$
|
134
|
|
$
|
284
|
|
$
|
921
|
|
|||||||
The changes in the fair value of NEE's consolidated subsidiaries' energy contract derivative instruments for the three and nine months ended September 30, 2012 were as follows:
|
|
|
Hedges on Owned Assets
|
|
||||||||||||||||
|
|
Trading
|
Non-
Qualifying
|
OCI
|
FPL Cost
Recovery
Clauses
|
NEE
Total
|
||||||||||||||
|
(millions)
|
|||||||||||||||||||
|
Three months ended September 30, 2012
|
|||||||||||||||||||
|
Fair value of contracts outstanding at June 30, 2012
|
$
|
113
|
|
$
|
899
|
|
$
|
4
|
|
$
|
(302
|
)
|
$
|
714
|
|
||||
|
Reclassification to realized at settlement of contracts
|
24
|
|
27
|
|
(2
|
)
|
185
|
|
234
|
|
|||||||||
|
Inception value of new contracts
|
6
|
|
—
|
|
—
|
|
—
|
|
6
|
|
|||||||||
|
Net option premium purchases (issuances)
|
13
|
|
—
|
|
—
|
|
—
|
|
13
|
|
|||||||||
|
Changes in fair value excluding reclassification to realized
|
33
|
|
(254
|
)
|
—
|
|
90
|
|
(131
|
)
|
|||||||||
|
Fair value of contracts outstanding at September 30, 2012
|
189
|
|
672
|
|
2
|
|
(27
|
)
|
836
|
|
|||||||||
|
Net margin cash collateral paid (received)
|
|
|
|
|
|
|
|
|
(120
|
)
|
|||||||||
|
Total mark-to-market energy contract net assets (liabilities) at September 30, 2012
|
$
|
189
|
|
$
|
672
|
|
$
|
2
|
|
$
|
(27
|
)
|
$
|
716
|
|
||||
53
|
|
|
Hedges on Owned Assets
|
|
||||||||||||||||
|
|
Trading
|
Non-
Qualifying
|
OCI
|
FPL Cost
Recovery
Clauses
|
NEE
Total
|
||||||||||||||
|
|
(millions)
|
||||||||||||||||||
|
Nine months ended September 30, 2012
|
|
|
|
|
|
||||||||||||||
|
Fair value of contracts outstanding at December 31, 2011
|
$
|
15
|
|
$
|
720
|
|
$
|
8
|
|
$
|
(501
|
)
|
$
|
242
|
|
||||
|
Reclassification to realized at settlement of contracts
|
49
|
|
(63
|
)
|
(6
|
)
|
560
|
|
540
|
|
|||||||||
|
Inception value of new contracts
|
6
|
|
2
|
|
—
|
|
—
|
|
8
|
|
|||||||||
|
Net option premium purchases (issuances)
|
(9
|
)
|
1
|
|
—
|
|
—
|
|
(8
|
)
|
|||||||||
|
Changes in fair value excluding reclassification to realized
|
128
|
|
12
|
|
—
|
|
(86
|
)
|
54
|
|
|||||||||
|
Fair value of contracts outstanding at September 30, 2012
|
189
|
|
672
|
|
2
|
|
(27
|
)
|
836
|
|
|||||||||
|
Net margin cash collateral paid (received)
|
|
|
|
|
|
|
|
|
(120
|
)
|
|||||||||
|
Total mark-to-market energy contract net assets (liabilities) at September 30, 2012
|
$
|
189
|
|
$
|
672
|
|
$
|
2
|
|
$
|
(27
|
)
|
$
|
716
|
|
||||
With respect to commodities,
NEE’s EMC, which is compri
sed of certain members of senior management, and NEE's chief executive officer are responsible for the overall approval of market risk management policies and the delegation of approval and authorization levels. The EMC and NEE's chief executive officer receive periodic updates on market positions and related exposures, credit exposures and overall risk management activities.
NEE uses a value-at-risk (VaR) model to measure commodity price market risk in its trading and mark-to-market portfolios. The VaR is the estimated nominal loss of market value based on a one-day holding period at a 95% confidence level using historical simulation methodology. As of
September 30, 2013
and December 31, 2012, the VaR figures are as follows:
|
Trading
|
Non-Qualifying Hedges and
Hedges in FPL Cost Recovery Clauses
(a)
|
Total
|
|||||||||||||||||||||||||||||||||
|
FPL
|
NEER
|
NEE
|
FPL
|
NEER
|
NEE
|
FPL
|
NEER
|
NEE
|
|||||||||||||||||||||||||||
|
(millions)
|
|||||||||||||||||||||||||||||||||||
|
December 31, 2012
|
$
|
—
|
|
$
|
3
|
|
$
|
3
|
|
$
|
34
|
|
$
|
88
|
|
$
|
76
|
|
$
|
34
|
|
$
|
87
|
|
$
|
76
|
|
||||||||
|
September 30, 2013
|
$
|
—
|
|
$
|
1
|
|
$
|
1
|
|
$
|
33
|
|
$
|
50
|
|
$
|
50
|
|
$
|
33
|
|
$
|
52
|
|
$
|
51
|
|
||||||||
|
Average for the nine months ended September 30, 2013
|
$
|
—
|
|
$
|
2
|
|
$
|
2
|
|
$
|
34
|
|
$
|
43
|
|
$
|
33
|
|
$
|
34
|
|
$
|
42
|
|
$
|
32
|
|
||||||||
______________________
|
(a)
|
Non-qualifying hedges are employed to reduce the market risk exposure to physical assets or contracts which are not marked to market. The VaR figures for the non-qualifying hedges and hedges in FPL cost recovery clauses category do not represent the economic exposure to commodity price movements.
|
Interest Rate Risk
NEE and FPL are exposed to risk resulting from changes in interest rates as a result of their respective issuances of debt, investments in special use funds and other investments. NEE and FPL manage their respective interest rate exposure by monitoring current interest rates, entering into interest rate contracts and using a combination of fixed rate and variable rate debt. Interest rate contracts are used to mitigate and adjust interest rate exposure when deemed appropriate based upon market conditions or when required by financing agreements.
54
The following are estimates of the fair value of NEE's and FPL's financial instruments that are exposed to interest rate risk:
|
|
September 30, 2013
|
|
December 31, 2012
|
|
||||||||||||
|
|
Carrying
Amount
|
Estimated
Fair Value
|
|
Carrying
Amount
|
Estimated
Fair Value
|
|
||||||||||
|
|
(millions)
|
|
||||||||||||||
|
NEE:
|
|
|
|
|
|
|
||||||||||
|
Fixed income securities:
|
|
|
|
|
|
|
||||||||||
|
Special use funds
|
$
|
1,985
|
|
$
|
1,985
|
|
(a)
|
$
|
1,979
|
|
$
|
1,979
|
|
(a)
|
||
|
Other investments:
|
|
|
|
|
|
|
||||||||||
|
Notes receivable
|
$
|
500
|
|
$
|
624
|
|
(b)
|
$
|
500
|
|
$
|
665
|
|
(b)
|
||
|
Debt securities
|
$
|
121
|
|
$
|
121
|
|
(a)
|
$
|
111
|
|
$
|
111
|
|
(a)
|
||
|
Long-term debt, including current maturities
|
$
|
27,788
|
|
$
|
28,744
|
|
(c)
|
$
|
26,647
|
|
(d)
|
$
|
28,874
|
|
(c)
|
|
|
Interest rate contracts - net unrealized losses
|
$
|
(143
|
)
|
$
|
(143
|
)
|
(e)
|
$
|
(311
|
)
|
$
|
(311
|
)
|
(e)
|
||
|
FPL:
|
|
|
|
|
|
|
||||||||||
|
Fixed income securities - special use funds
|
$
|
1,540
|
|
$
|
1,540
|
|
(a)
|
$
|
1,526
|
|
$
|
1,526
|
|
(a)
|
||
|
Long-term debt, including current maturities
|
$
|
8,829
|
|
$
|
9,634
|
|
(c)
|
$
|
8,782
|
|
$
|
10,421
|
|
(c)
|
||
————————————
|
(a)
|
Estimated using quoted market prices for these or similar issues.
|
|
(b)
|
Estimated using a discounted cash flow valuation technique based on certain observable yield curves and indices considering the credit profile of the borrower.
|
|
(c)
|
Estimated using either quoted market prices for the same or similar issues or discounted cash flow valuation technique, considering the current credit spread of the debtor.
|
|
(d)
|
Also includes long-term debt reflected in liabilities associated with assets held for sale on the condensed consolidated balance sheets, for which the carrying amount approximates fair value.
|
|
(e)
|
Modeled internally using discounted cash flow valuation technique and applying a credit valuation adjustment.
|
The special use funds of NEE and FPL consist of restricted funds set aside to cover the cost of storm damage for FPL and for the decommissioning of NEE's and FPL's nuclear power plants. A portion of these funds is invested in fixed income debt securities primarily carried at estimated fair value. At FPL, changes in fair value, including any OTTI losses, result in a corresponding adjustment to the related liability accounts based on current regulatory treatment. The changes in fair value of NEE's non-rate regulated operations result in a corresponding adjustment to OCI, except for impairments deemed to be other than temporary, including any credit losses, which are reported in current period earnings. Because the funds set aside by FPL for storm damage could be needed at any time, the related investments are generally more liquid and, therefore, are less sensitive to changes in interest rates. The nuclear decommissioning funds, in contrast, are generally invested in longer-term securities, as decommissioning activities are not scheduled to begin until at least 2030 (2032 at FPL).
As of
September 30, 2013
, NEE had interest rate contracts with a notional amount of approximately $7.6 billion related to long-term debt issuances, of which $2.1 billion are fair value hedges at NEECH that effectively convert fixed-rate debt instruments to variable-rate instruments. The remaining $5.5 billion of notional amount of interest rate contracts relate to cash flow hedges to manage exposure to the variability of cash flows associated with variable-rate debt instruments, all of which relate to NEER debt issuances. At
September 30, 2013
, the estimated fair value of NEE's fair value hedges and cash flow hedges was approximately $21 million and $(164) million, respectively. See Note 2.
Based upon a hypothetical 10% decrease in interest rates, which is a reasonable near-term market change, the net fair value of NEE's net liabilities would increase by approximately $1,001 million ($493 million for FPL) at
September 30, 2013
.
Equity Price Risk
NEE and FPL are exposed to risk resulting from changes in prices for equity securities. For example, NEE’s nuclear decommissioning reserve funds include marketable equity securities primarily carried at their market value of approximately $2,589 million and $2,211 million ($1,615 million and $1,392 million for FPL) at
September 30, 2013
and
December 31, 2012
, respectively. At
September 30, 2013
, a hypothetical 10% decrease in the prices quoted by stock exchanges, which is a reasonable near-term market change, would result in a $248 million ($157 million for FPL) reduction in fair value. For FPL, a corresponding adjustment would be made to the related liability accounts based on current regulatory treatment, and for NEE’s non-rate regulated operations, a corresponding adjustment would be made to OCI to the extent the market value of the securities exceeded amortized cost and to OTTI loss to the extent the market value is below amortized cost.
Currency Exchange Rate Risk
At
September 30, 2013
, with respect to certain debt issuances and borrowings, NEECH has two cross currency swaps to hedge against currency movements with respect to both interest and principal payments and a cross currency swap to hedge against currency and interest rate movements with respect to both interest and principal payments. At
September 30, 2013
and
December 31, 2012
, the fair value of cross currency swaps was approximately $(117) million and $(66) million, respectively.
55
Credit Risk
NEE and its subsidiaries are also exposed to credit risk through their energy marketing and trading operations. Credit risk is the risk that a financial loss will be incurred if a counterparty to a transaction does not fulfill its financial obligation. NEE manages counterparty credit risk for its subsidiaries with energy marketing and trading operations through established policies, including counterparty credit limits, and in some cases credit enhancements, such as cash prepayments, letters of credit, cash and other collateral and guarantees.
Credit risk is also managed through the use of master netting agreements. NEE’s credit department monitors current and forward credit exposure to counterparties and their affiliates, both on an individual and an aggregate basis. For all derivative and contractual transactions, NEE’s energy marketing and trading operations, which includes FPL’s energy marketing and trading division, are exposed to losses in the event of nonperformance by counterparties to these transactions. Some relevant considerations when assessing NEE’s energy marketing and trading operations’ credit risk exposure include the following:
|
•
|
Operations are primarily concentrated in the energy industry.
|
|
•
|
Trade receivables and other financial instruments are predominately with energy, utility and financial services related companies, as well as municipalities, cooperatives and other trading companies in the U.S.
|
|
•
|
Overall credit risk is managed through established credit policies and is overseen by the EMC.
|
|
•
|
Prospective and existing customers are reviewed for creditworthiness based upon established standards, with customers not meeting minimum standards providing various credit enhancements or secured payment terms, such as letters of credit or the posting of margin cash collateral.
|
|
•
|
Master netting agreements are used to offset cash and non-cash gains and losses arising from derivative instruments with the same counterparty. NEE’s policy is to have master netting agreements in place with significant counterparties.
|
Based on NEE’s policies and risk exposures related to credit, NEE and FPL do not anticipate a material adverse effect on their financial statements as a result of counterparty nonperformance. As of
September 30, 2013
, approximately 97% of NEE’s and 100% of FPL’s energy marketing and trading counterparty credit risk exposure is associated with companies that have investment grade credit ratings.
Item 3.
Quantitative and Qualitative Disclosures About Market Risk
See Management's Discussion - Energy Marketing and Trading and Market Risk Sensitivity.
|
(a)
|
Evaluation of Disclosure Controls and Procedures
|
As of
September 30, 2013
, each of NEE and FPL had performed an evaluation, under the supervision and with the participation of its management, including NEE's and FPL's chief executive officer and chief financial officer, of the effectiveness of the design and operation of each company's disclosure controls and procedures (as defined in the Securities Exchange Act of 1934 Rules 13a-15(e) and 15d-15(e)). Based upon that evaluation, the chief executive officer and the chief financial officer of each of NEE and FPL concluded that the company's disclosure controls and procedures were effective as of
September 30, 2013
.
|
(b)
|
Changes in Internal Control over Financial Reporting
|
NEE and FPL are continuously seeking to improve the efficiency and effectiveness of their operations and of their internal controls. This results in refinements to processes throughout NEE and FPL. However, there has been no change in NEE's or FPL's internal control over financial reporting (as defined in the Securities Exchange Act of 1934 Rules 13a-15(f) and 15d-15(f)) that occurred during NEE's and FPL's most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, NEE's or FPL's internal control over financial reporting.
NEE and FPL are parties to various legal and regulatory proceedings in the ordinary course of their respective businesses. For information regarding legal proceedings that could have a material effect on NEE or FPL, see Item 3. Legal Proceedings and Note 13 - Legal Proceedings to Consolidated Financial Statements in the 2012 Form 10-K and Note 10 - Spain Solar Projects and - Legal Proceedings herein. Such descriptions are incorporated herein by reference.
56
There have been no material changes from the risk factors disclosed in the 2012 Form 10-K. The factors discussed in Part I, Item 1A. Risk Factors in the 2012 Form 10-K, as well as other information set forth in this report, which could materially adversely affect NEE's and FPL's business, financial condition, results of operations and prospects should be carefully considered. The risks described in the 2012 Form 10-K are not the only risks facing NEE and FPL. Additional risks and uncertainties not currently known to NEE or FPL, or that are currently deemed to be immaterial, also may materially adversely affect NEE's or FPL's business, financial condition, results of operations and prospects.
|
(c)
|
Information regarding purchases made by NEE of its common stock during the
three months ended September 30, 2013
is as follows:
|
|
Period
|
Total Number
of Shares Purchased
(a)
|
Average Price Paid
Per Share
|
Total Number of Shares
Purchased as Part of a
Publicly Announced
Program
|
Maximum Number of
Shares that May Yet be
Purchased Under the
Program
(b)
|
|||||||
|
7/1/13 - 7/31/13
|
—
|
|
$
|
—
|
|
—
|
13,274,748
|
||||
|
8/1/13 - 8/31/13
|
5,098
|
|
$
|
83.70
|
|
—
|
13,274,748
|
||||
|
9/1/13 - 9/30/13
|
516
|
|
$
|
79.03
|
|
—
|
13,274,748
|
||||
|
Total
|
5,614
|
|
$
|
83.27
|
|
—
|
|||||
|
(a)
|
Includes: (1) in August 2013, shares of common stock withheld from employees to pay certain withholding taxes upon the vesting of stock awards granted to such employees under the NextEra Energy, Inc. Amended and Restated 2011 Long-Term Incentive Plan and the NextEra Energy, Inc. Amended and Restated Long-Term Incentive Plan (former LTIP); and (2) in September 2013, 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.
|
|
(a)
|
None
|
|
(b)
|
None
|
|
(c)
|
Other events
|
|
(i)
|
Reference is made to Item 1. Business - NEE's Operating Subsidiaries - FPL - FPL Sources of Generation - Nuclear Operations - Nuclear Unit Scheduled Refueling Outages in the 2012 Form 10-K.
|
The next scheduled nuclear refueling outage for Turkey Point Unit No. 3 is expected to begin in March 2014.
|
(ii)
|
Reference is made to Item 1. Business - NEE's Operating Subsidiaries - FPL - FPL Sources of Generation - Nuclear Operations - Disposition of Spent Nuclear Fuel in the 2012 Form 10-K.
|
In August 2013, the U.S. Court of Appeals for the District of Columbia (D.C. Circuit) issued an order requiring the NRC to proceed with the legally mandated licensing process for a nuclear waste repository at Yucca Mountain. As a result, in August 2013, the NRC issued an order to the participants in the licensing proceeding seeking their views on how the NRC should proceed with the licensing process.
|
(iii)
|
Reference is made to Item 1. Business - NEE Environmental Matters - Environmental Regulations - Regulation of GHG Emissions in the 2012 Form 10-K.
|
In October 2013, the U.S. Supreme Court granted a request by several petitioners for review of the D.C. Circuit's decision which upheld the EPA's greenhouse gas (GHG) regulations. The U.S. Supreme Court granted review on the limited question of whether the EPA permissibly determined that its regulation of GHG emissions from new motor vehicles triggered permitting requirements under the Clean Air Act for stationary sources that emit GHG. The U.S. Supreme Court is expected to hear oral arguments between January and June 2014.
57
|
Exhibit
Number
|
Description
|
NEE
|
FPL
|
|||
|
*4(a)
|
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated September 21, 2010, creating the Series D Debentures due September 1, 2015 (filed as Exhibit 4(c) to Form 8-K dated September 15, 2010, File No. 1-8841)
|
x
|
||||
|
*4(b)
|
Letter, dated August 9, 2013, from NextEra Energy Capital Holdings, Inc. to The Bank of New York Mellon, as trustee, setting forth certain terms of the Series D Debentures effective August 9, 2013 (filed as Exhibit 4(b) to Form 8-K dated August 9, 2013, File No. 1-8841)
|
x
|
||||
|
*4(c)
|
Purchase Contract Agreement, dated as of September 1, 2013, between NextEra Energy, Inc. and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(a) to Form 8-K dated September 25, 2013, File No. 1-8841)
|
x
|
||||
|
*4(d)
|
Pledge Agreement, dated as of September 1, 2013, between NextEra Energy, Inc., Deutsche Bank Trust Company Americas, as Collateral Agent, Custodial Agent and Securities Intermediary, and The Bank of New York Mellon, as Purchase Contract Agent (filed as Exhibit 4(b) to Form 8-K dated September 25, 2013, File No. 1-8841)
|
x
|
||||
|
*4(e)
|
Officer's Certificate of NextEra Energy Capital Holdings, Inc., dated September 25, 2013, creating the Series G Debentures due September 1, 2018 (filed as Exhibit 4(c) to Form 8-K dated September 25, 2013, File No. 1-8841)
|
x
|
||||
|
12(a)
|
Computation of Ratios
|
x
|
||||
|
12(b)
|
Computation of Ratios
|
x
|
||||
|
31(a)
|
Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of NextEra Energy, Inc.
|
x
|
||||
|
31(b)
|
Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer of NextEra Energy, Inc.
|
x
|
||||
|
31(c)
|
Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of Florida Power & Light Company
|
x
|
||||
|
31(d)
|
Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer of Florida Power & Light Company
|
x
|
||||
|
32(a)
|
Section 1350 Certification of NextEra Energy, Inc.
|
x
|
||||
|
32(b)
|
Section 1350 Certification of Florida Power & Light Company
|
x
|
||||
|
101.INS
|
XBRL Instance Document
|
x
|
x
|
|||
|
101.SCH
|
XBRL Schema Document
|
x
|
x
|
|||
|
101.PRE
|
XBRL Presentation Linkbase Document
|
x
|
x
|
|||
|
101.CAL
|
XBRL Calculation Linkbase Document
|
x
|
x
|
|||
|
101.LAB
|
XBRL Label Linkbase Document
|
x
|
x
|
|||
|
101.DEF
|
XBRL Definition Linkbase Document
|
x
|
x
|
|||
_________________________
*Incorporated herein by reference
NEE and FPL agree to furnish to the SEC upon request any instrument with respect to long-term debt that NEE and FPL have not filed as an exhibit pursuant to the exemption provided by Item 601(b)(4)(iii)(A) of Regulation S-K.
58
|
SIGNATURES
|
|||
|
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.
|
|||
|
Date:
|
November 1, 2013
|
||
|
NEXTERA ENERGY, INC.
(Registrant)
|
|||
|
CHRIS N. FROGGATT
|
|||
|
Chris N. Froggatt
Vice President, Controller and Chief Accounting Officer
of NextEra Energy, Inc.
(Principal Accounting Officer of NextEra Energy, Inc.)
|
|||
|
FLORIDA POWER & LIGHT COMPANY
(Registrant)
|
|||
|
KIMBERLY OUSDAHL
|
|||
|
Kimberly Ousdahl
Vice President, Controller and Chief Accounting Officer
of Florida Power & Light Company
(Principal Accounting Officer of
Florida Power & Light Company)
|
|||
59
TABLE OF CONTENTS
Part I - Financial InformationItem 1. Financial StatementsItem 2. Management's Discussion and Analysis Of Financial Condition and Results Of OperationsItem 3. Quantitative and Qualitative Disclosures About Market RiskItem 4. Controls and ProceduresPart II - Other InformationItem 1. Legal ProceedingsItem 1A. Risk FactorsItem 2. Unregistered Sales Of Equity Securities and Use Of ProceedsItem 5. Other InformationItem 6. Exhibits